OGV Australia Issue 6 Marine & Lifting

Global Gravity expands worldwide with TubeLock® Global Gravity expands global footprint, bringing

&

solution for tubular transportation to key markets

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Welcome to the sixth and the final issue of 2025 of our OGV Energy Australia magazine on the theme of Marine and Lifting.

We have made it to issue six and are close to marking one year of OGV Group Australia, what a year it has been! Establishing in a new region, exploring new events all over Australia and APAC, not to mention making many new connections, friends and catching up with clients from across the globe looking at opportunities in Australia.

This first year would not have been possible without the support from our amazing clients old and new as well as the continuous guidance and encouragement from my superb colleagues in Aberdeen. Thank you endlessly.

Rounding off this year, we are thrilled to have Global Gravity as our front cover superstar and feature article. From humble beginnings in Denmark to global expansion across 8 regions, Global Gravity explains how their critical tubular handling solutions are changing the game in the oil and gas market. With their sights set on development in Australia and APAC, Dave Craig - General Manager APAC - details the opportunities in utilising their TubeLock technology to efficiently optimise operations in costs, time and most importantly, safety. To find out more, please turn our feature article on page 4.

We are also delighted to provide contributions in this issue from SLB, Rio Tinto, Three60 Energy and many more.

There are also comprehensive reviews from regions across the globe as well as the Mining industry here in Australia.

That’s all from me and OGV Group Australia for 2025 but we will be back and bigger for 2026 - keep your eyes peeled for

new happening in the New Year!

Global Gravity’s TubeLock® Targets Growth Across the World’s

Oil & Gas Markets

Offshore oil and gas operations depend on precision, safety, and efficiency. One of the clearest examples of this is tubular handling and transport, a task that has long been known as hazardous, time-consuming and expensive.

In the offshore oil and gas industry, where even small mistakes can have major consequences, innovation in safety and efficiency isn’t just welcome - it’s essential.

Since its founding in 2011 in the Danish port city of Esbjerg, Global Gravity has built its reputation on precisely that: practical innovation tailored to the unique challenges of the offshore oil and gas sector.

Global Gravity entered the oil and gas market with a clear purpose: to make tubular handling safer, efficient, and more optimised for the client’s operation. Anyone who has spent time on a rig floor or quayside knows the risks associated with traditional methods of pipe transportation.

The foundation of Global Gravity’s success is TubeLock®, the company’s patented Tubular Transport Running System (TTRS), widely recognised as a transformative step forward in how tubulars are handled, stored, and transported offshore.

Now, Global Gravity is taking its message and method further overseas. In addition to its headquarters in Denmark, as of this year, the company has established offices in Norway, the UK, Qatar, and Australia, signalling a decisive commitment to serving operators and drilling contractors worldwide.

What makes TubeLock® different

TubeLock® is a patented, all-in-one pipe handling system that enables all preparation - drifting, tallying, and fitting of centralisersto be completed onshore, making offshore handling safer and smarter. TubeLock® is engineered for ultimate efficiency and protection, both onshore and offshore.

Its patented smart, stackable design makes it easy to transport by road, vessel, or directly to the rig, while allowing operators to run pre-numbered pipe one by one straight from the frame.

This innovative approach minimises manual handling, enhances safety, and streamlines the entire pipe-handling process.

TubeLock® effortlessly accommodates a wide range of pipe types, including OCTG, sand screens, assemblies, and more, in sizes from 2-3/8” to 20”.

Best of all, every TubeLock® system can be tailored to meet specific client needs, delivering a custom-fit solution that improves both safety and operational performance across any project.

TubeLock® is more than just a piece of equipment; it represents a fundamental shift in the way tubulars are managed offshore.

The advantages of using TubeLock®:

• Safety: Minimising risk to personnel and equipment during loading, transport, and running. With no slings to remove and far less pipe movement, the risk of dropped objects and personnel injury is reduced by at least 50%.

• Efficiency: Streamlining operations to reduce vessel time and non-productive delays. Operators report time savings of up to 50% on tubular handling processes, freeing cranes and deck crews for more critical drilling operations.

• Space: TubeLock® requires roughly half the deck space compared to traditional methods, a major advantage on crowded offshore platforms.

• Environmental impact: An independent study confirmed TubeLock® reduces CO₂ emissions per well from 52 tonnes to 16 tonnes, thanks to shorter vessel times and lower crane usage.

The design also considers practicalities. Manufactured from lightweight aluminium, no single TubeLock® component weighs more than 15 kilos, easing manual handling while avoiding galvanic corrosion with chrome alloy tubulars. For high-value assets such as chrome and super-chrome tubulars, TubeLock® provides superior protection against damage compared with slinging or transport baskets.

Importantly, TubeLock® has been certified under DNV ST-0378, ISO 9001, NORSOK R02 and meets LOLER recommendations, making it a globally recognised, best-practice solution. The company is also a member of the Lifting Equipment Engineers Association (LEEA) and the IADC Southern Arabian Peninsula Chapter.

Setting a new standard

TubeLock® has already established itself as an industry benchmark. Drilling contractors and operators adopting the system consistently report safer operations, faster turnarounds, and reduced environmental impact.

In a world where the cost of downtime can reach into the millions per day, cutting half the time spent on pipe handling has a measurable financial impact. And beyond the numbers, TubeLock® is transforming the daily reality of offshore crews by removing unnecessary risks.

Global Gravity’s CEO, Tom Rasmussen commented “TubeLock® is more than a piece of equipment, it represents a change in how the industry approaches tubular handling. By replacing unpredictable, manual processes with a structured and controlled system, we’re helping operators achieve safer, more efficient, and more consistent operations offshore.”

“Since joining Global

the

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focus on introducing Tubelock® and showcasing the full range of benefits we can bring to clients in the APAC region”

Expanding horizons

Global Gravity has expanded with purpose from its roots in Denmark, carefully planning its global footprint to position TubeLock® in the markets that matter most.

Offices in Norway and in the UK brought Global Gravity closer to North Sea operators, among the earliest adopters of TubeLock®. In Qatar, where the company has been active since 2019, the official opening of an office in 2025 is built on years of established customer relationships, creating a permanent base in the Middle East - a region where operators face the same critical demands for safety and efficiency.

Now, with its latest expansion into Australia, Global Gravity is turning its focus to the growing Asia-Pacific (APAC) region.

Why APAC and why now?

The decision to establish an office in Australia is both strategic and timely. APAC remains one of the most dynamic oil and gas regions in the world. Offshore projects across the region have operators demanding solutions that improve safety, reduce costs, and limit environmental impact.

Global Gravity sees the APAC region as a strong growth opportunity for TubeLock®, driven by increasing offshore activity, tightening safety and emissions regulations, and the growing need for more efficient tubular handling solutions. The company’s ambition is clear: to establish TubeLock® as the standard system for transportation and handling all types of pipes used by drilling rigs within the region.

By establishing a presence there, the company is demonstrating its long-term commitment to supporting operators across the region.

The new office is led by industry veteran Dave Craig, who has relocated from Aberdeen to oversee APAC operations. Dave brings extensive experience in lifting and drilling operations and is eager for the challenge ahead.

Focus on the APAC market

The decision to establish the APAC headquarters in Perth was both practical and strategic.

Global Gravity has had active operations in Western Australia since 2022, also completing projects in New Zealand during that time so makes it the ideal base to support those working on the North-West Shelf and beyond. At the same time, Perth offers strong logistical connectivity across the wider APAC region, enabling Global Gravity to serve customers efficiently wherever they operate.

This dual advantage ensures that Global Gravity is not only close to its core Australian customer base but also well-positioned to play a meaningful role across APAC’s oil and gas sector. 

Gravity

2019, I’ve witnessed

growth

adoption

TubeLock® across the industry as the go-to system

tubular transportation. I’m excited to now

Dave Craig commented:

integrated bypass maintains production during isolation

Dual Leak-Tight Seals

Double Block & Bleed Isolation

Isolated Pipeline

Monitored Zero-Energy Zone

The BISEP® has an ex tensive track record and provides pioneering double block and bleed isolation while

dual seals provide tested, proven and fully monitored leak-tight isolation, ever y time, any pressure.

COMMUNITY news

Tide Breaker opens call for startups to join new digital initiative alongside global operators

Aberdeen tech company Elementz has officially opened the call for applications for its new digital accelerator initiative with AI startup companies now formally invited to apply.

Spearheaded by Elementz, a subsea asset integrity management software company, Tide Breaker is a digital initiative designed to fast-track the development of artificial intelligence (AI) in subsea operations.

Launched last week (October 30th) at Aberdeen’s ONE Tech Hub, Tide Breaker: Powering the Subsea Start Up Wave, attracted over 75 attendees from across the energy, technology, and innovation sectors, including oil and gas, renewables, software, and industry bodies. 

New Partnership Strengthens Well Intervention Capabilities Across Australia

Unity Well Integrity (Unity), an international well integrity and decommissioning specialist, has announced a strategic partnership with Clear Cut Interventions (CCI) Australia, a respected provider of well intervention services to the Australian oil and gas industry.

The collaboration marks a significant step forward in delivering advanced intervention and well integrity solutions to operators across Australia. By addressing the offshore realities of limited POB, restricted deck space and crane capacity, the partnership ensures operators can execute critical well integrity work with greater efficiency, safety and certainty. 

Thyra Paints the Oil Industry Pink - The fight against breast cancer deserves attention all year round.

For years, Izomax has proudly supported the Pink Ribbon campaign through annual donations each October. This year, they wanted to take their commitment one step further and make the important fight against breast cancer visible every single day of the year.

That’s why we’re introducing Thyra. She’s one of the AOGVs in our fleet that repair and maintain pipelines all over the world. From now on, Thyra will stand out, not in yellow, but in pink. And every time she’s sent out on a new assignment, Izomax will donate NOK 10,000 to the Pink Ribbon campaign. 

ABL to support platform installations and rig moves for Chevron in Gulf of Thailand

ABL has received an award of work order from Chevron Thailand Exploration and Production, Ltd., Chevron Offshore (Thailand) Ltd. and Chevron Pattani Limited to provide marine warranty survey (MWS) and thirdparty support services in connection with wellhead platform installations and jack-up rig moving in the Gulf of Thailand.

ABL’s scope of work includes MWS services for wellhead platform installations including other associated services. The MWS scope comprises desktop document reviews, suitability surveys, loadout approvals, towage approvals and lifted installation approvals.

ABL’s operations in Thailand will head up the deliverables, supported by ABL’s offices in Malaysia and Singapore. 

Direct Travel Acquires ATPICreates Modern Global Travel Management Powerhouse

Direct Travel, Inc., a leader in corporate travel management, has announced the acquisition of its long-time strategic partner, ATPI, creating one of the world’s largest travel management companies.

Together, the two companies will drive over $6 billion in annual total travel volume and offer leading technologies and unparalleled service across global corporate, leisure, events, and specialized travel sectors.

The acquisition of ATPI, one of the most experienced and long-established international travel and event management companies, serves as a natural progression of the companies’ multi-year collaboration to serve the business travel needs of global corporate clients. 

SLB has signed a definitive agreement to acquire RESMAN Energy Technology, a global leader in wireless reservoir surveillance solutions, in a move aimed at strengthening its production and recovery portfolio

RESMAN’s proprietary tracer technologies, already in use across oil, gas, CO₂ storage, and geothermal projects, allow operators to track fluid movement in reservoirs with precision down to parts per trillion. These insights enable faster interventions, extended well life, and optimized recovery while minimizing operational disruptions. 

SLB acquires RESMAN to enhance tracer technology, recovery solutions

GAC is a global provider of shipping, logistics and marine services. Emphasising world-class performance, a long-term approach, innovation, ethics and a strong human touch, we deliver a flexible and value-adding portfolio to help customers achieve their strategic goals.

Established since 1956, GAC employs over 7,500 people at more than 300 offices in over 50 countries worldwide.

www.gac.com

Film-Ocean provides innovative subsea solutions to the global offshore energy industry. We specialise in providing a turnkey managed service for the subsea inspection of floating assets and have ABS, BV, DNV and Lloyd’s approval for the inspection of the long term fixed moored system including our chain measuring equipment.

www.film-ocean.com

Dron & Dickson are specialists in integrated supply, installation and maintenance of harsh & hazardous area electrical equipment. Our UK network of wholesale branches can supply quality brand-name electrical equipment from all the leading manufacturers supported by the highest level of customer service.

www.drondickson.com

The Orphie business of i2S is a specialist in the design of complex underwater imaging systems.

Our aim is to make underwater operations more efficient, more cost-effective and safer, thanks to our patented technology.

www.i2s-orphie.com

Provider of specialist products, services and engineered solutions for renewable and conventional energy markets.

www.glacierenergy.com

Destec On-Site Services provide specialist engineering solutions across the UK and internationally, supporting a broad spectrum of industries including chemical and petrochemical, offshore, power generation (renewable and nuclear), marine, steel, mining, rail, fabrication, and vessel manufacturing.

www.destec.co.uk

At WellSense, we’re on a mission to extend the life of oil and gas fields, maximize well performance, and ensure effective well abandonment through innovative, practical solutions.

www.well-sense.co.uk

Penspen’s global teams design, maintain, and optimise energy infrastructure to improve access to secure and sustainable energy for communities worldwide.

www.penspen.com

Deepsea Technologies, Inc. specializes in the development, engineering and manufacturing of standard and customized equipment for the following applications: subsea production systems, SURF, subsea intervention, offshore & onshore drilling, and others. DTI was established in 2001 and headquartered in Houston, TX operating under an ISO 9001:2015 certified Quality Management System.

www.deepsea-tech.com/

Australia Energy Review

By Tsvetana Paraskova

Australia’s Energy Firms Upbeat on Demand

Australia’s biggest oil and gas companies projected optimism at their earnings and outlook releases, while Australia’s government continues to work to boost the rollout of renewable energy.

Solid Earnings and Demand Expectations

Following the withdrawn bid from an Abu Dhabi-led consortium to buy Santos, the Australian energy giant reported solid quarterly results for the third quarter of 2025, as the firm transitions from a period of high capital intensity to one that it expects to deliver stronger returns for shareholders.

Third-quarter sales volumes were lower than the second quarter, mainly due to maintenance activities in Western Australia, lower crude oil volumes due to timing of liftings, and lower third-party gas purchases. January-September sales volumes were slightly higher than the prior year.

Santos narrowed its production guidance for this year to between 89 million and 91 million barrels of oil equivalent (boe), down from the previous guidance of 90-95 million boe.

The downgrade primarily reflects a slower-thananticipated start-up of the floating production, storage, and offloading vessel (FPSO) at the new Barossa LNG project and the impact of floods on the company’s production in the Cooper Basin. Going forward, Santos expects the Barossa LNG project in Australia and the Pikka oil project in Alaska to boost its oil and gas production by 30 percent by 2027, compared to 2024 levels.

Xsix months of operations, September 2024 –March 2025.

Moomba CCS demonstrates the real potential for large-scale emissions reduction to be delivered by carbon capture and storage projects in Australia, according to CEO Gallagher.

Momentum is also building around our Narrabri Gas Project, with strong market interest reflected in recent MOUs and ongoing engagement with key stakeholders.

“With around $1.4 billion of free cash flow from operations generated year-to-date, Santos is well positioned to deliver strong shareholder returns with imminent production growth as we bring Barossa LNG online and move closer to the start-up of Pikka,” said Santos managing director and CEO Kevin Gallagher.

“Momentum is also building around our Narrabri Gas Project, with strong market interest reflected in recent MOUs and ongoing engagement with key stakeholders. Narrabri is the key to solving east coast gas supply concerns and would be a competitive supply source for local industry for decades to come,” Gallagher added.

Santos has also announced that its Moomba Carbon Capture and Storage (CCS) project achieved a major milestone for emissions reduction technology in Australia after receiving the single largest issuance of Australian Carbon Credit Units (ACCUs) from the Clean Energy Regulator (CER). The CER confirmed the issuance of 614,133 ACCUs to Santos under the approved CCS method, covering the Moomba CCS project’s initial

“Policymakers should seize the opportunity to deploy CCS to reduce emissions faster, at scale and cost competitively – particularly when Australia has a unique and natural advantage in carbon capture and storage that is complemented by a well-established, worldclass regulatory regime administered by the Clean Energy Regulator,” the executive added.

The other major Australia-based oil and gas producer, Woodside, reported solid production for the third quarter and raised its full-year guidance on the back of strong performance across assets.

Guidance was revised up in the range 192 –197 million barrels of oil equivalent (boe) for 2025, up from 188 million boe – 195 million boe previously anticipated. Unit production cost is now seen at between $7.60 and $8.10 per barrel this year, down from the previous guidance of $8.0 - $8.50 a barrel.

The company’s Scarborough Energy Project is now 91 percent complete and on track for first LNG in the second half of 2026, chief executive officer Meg O’Neill said.

At the 2025 Capital Markets Day in November, Woodside outlined its strategy to thrive through the energy transition and deliver long-term shareholder value by meeting rising global demand for affordable, reliable, lower-carbon energy.

“Over the next decade, with disciplined capital management, we will execute our strategy by maximising performance from our base business, delivering cash-generative projects to sustain and grow the business and creating the next wave of future opportunities for long-term returns for our shareholders,” O’Neill said.

Woodside expects its net operating cash to rise to around US$9 billion by the early 2030s, representing a more than 6 percent compound annual growth rate in sales and cash flow from 2024 and providing a pathway to a 50-percent increase in dividend per share from 2032.

“Our strategy is supported by ongoing robust global demand for our products. Woodside’s major growth projects will capitalise on this demand, with the Beaumont New Ammonia project expecting first ammonia this year, the Scarborough Energy Project on track to begin LNG shipments in the second half of next year, the offshore Mexico Trion field targeting first oil in 2028, and Louisiana LNG targeting startup in 2029,” O’Neill noted.

“With global LNG demand forecast to grow 60% by 2035, Woodside’s increasing scale across the Atlantic and Pacific basins, combined with our marketing and trading business, optimises our capability to meet customer needs.”

APA Group, for its part, has launched construction of the Sturt Plateau Pipeline (SPP), which is the crucial first-stage link to enable Beetaloo gas to reach power generation assets that keep the lights on across the Northern Territory.

SPP will play an important role in transporting Beetaloo gas to APA’s existing Amadeus Gas Pipeline, to power generation assets in Darwin.

Over the coming months the 37-kilometre pipeline will be welded together to ensure Beetaloo gas can flow in 2026.

“The SPP will help ensure Beetaloo gas is available to power the Territory, a critical first step in the basin’s development. Households and businesses in Darwin will be the first beneficiaries of this new infrastructure,” APA CEO and managing director Adam Watson said.

Clean Energy Industry Welcomes Reforms

The Clean Energy Council has welcomed the federal government’s proposed reforms to the Environment Protection and Biodiversity Conservation Act 1999 (EPBC Act), describing them as a timely and balanced step towards protecting Australia’s environment while delivering the clean, reliable electricity the nation needs.

The long-anticipated reforms are pragmatic and thorough, providing the industry with greater clarity for the task ahead, of delivering a timely and successful renewables rollout, Clean Energy Council CEO, Jackie Trad, said.

The broader reform package also pledges to have clearer, more consistent guidance for the clean energy sector and a more streamlined approval process. Projects will be assessed and decided more efficiently, without compromising rigorous environmental standards, according to the proposed changes.

“The reforms provide us the certainty and confidence to continue delivering the

renewable energy projects that power Australian homes and businesses, while safeguarding the environment for generations to come,” Trad commented.

Despite growing power demand, wholesale electricity prices across all National Electricity Market (NEM) regions fell during the September 2025 quarter, thanks to higher renewable energy output and less market volatility, the Australian Energy Market Operator’s (AEMO’s) Quarterly Energy Dynamics report has shown.

Wholesale electricity prices for the NEM averaged AUS$87 per megawatt hour (MWh) in the September quarter, down by 27 percent year-on-year and down 38 percent compared to the second quarter of 2025, the report found.

“The impact of increasing renewable energy and storage connecting to the NEM became more evident in September when milder temperatures and less cloudy days led to a new 77.2% renewable contribution record on 22 September – up from 75.6% in Q4 2024,” said Violette Mouchaileh, AEMO Executive General Manager Policy and Corporate Affairs. 

MINING Review

By Tsvetana Paraskova

Despite a slowdown in greenfield exploration, Australia is advancing many projects for mining critical minerals and rare earth elements as it looks to boost Western supply of the materials critical for the energy transition and the defence and auto manufacturing industries.

Greenfield Exploration Slows

Expenditure for greenfield mineral exploration fell in the April-June quarter compared to the same period of 2024, the Australian Association of Mining and Exploration Companies (AMEC) said, commenting on the quarterly data by the Australian Bureau of Statistics (ABS).

The statistics data showed some solid numbers, along with a reason for concern, AMEC said in September.

The figures revealed expenditure for national greenfield exploration fell by 17 percent to AUS$253.2 million, compared to AUS$305.6 million in the June 2024 quarter. National brownfields exploration remained relatively flat year on year at AUS$753.1 million.

Led by an uptick in brownfield mineral exploration, Western Australia and Tasmania were the only jurisdictions to buck the trend, with 10.2 percent and 19.8 percent growth in total exploration spend, respectively, AMEC said.

Gold exploration boomed in the June quarter, as global gold demand and prices soar in a tense geopolitical global context.

“Gold has been on an incredible run of late and these stats back it up. It’s also a sizeable indicator that things are starting to improve,” said AMEC Chief Executive Officer, Warren Pearce.

“The introduction of clear timeframes, coupled with transparent consultation processes, will help unlock investment and reinforce WA’s reputation as a world-class destination for exploration and mining industries.”

Gold has been on an incredible run of late and these stats back it up. It’s also a sizeable indicator that things are starting to improve

“In fact, gold was responsible for 40 per cent of all exploration activity recorded across the quarter.”

However, “This continuing reduction in greenfields activity has critical implications for future new project discovery and development and filling the pipeline needed to ensure the future economic prosperity of the nation,” Pearce added.

Overall, the numbers are solid, AMEC noted. The total national exploration spend for FY2025 was AUS$3.83 billion, with brownfields accounting for AUS$2.82 billion and greenfields AUS$1.01 billion. Total metres drilled were only slightly down by 1 percent compared to last year.

AMEC also welcomed the introduction of a new State Development Bill 2025 in Western Australia as it sees the new legislation as “a significant step forward in ensuring investment certainty and timely decision making for strategically important projects across Western Australia.”

“WA’s approvals system is already strong, this ensures we can keep those high standards, but provides industry greater certainty about how and when decisions will be made,” AMEC’s Pearce said.

In addition, AMEC welcomed the joint AUS$600 million investment by the Federal and Queensland Governments to keep Glencore’s Mount Isa copper smelter and Townsville copper refinery operational.

“This investment ensures Australia retains critical processing capability at a time when global demand for our minerals is at a premium,” Pearce said in a statement.

Critical Minerals Projects Move Forward

The Queensland Government has announced a AUS$10 million investment in Vecco Group’s mine and commercial-scale electrolyte facility to establish Australia’s first vanadium battery supply chain

Using vanadium sourced from Julia Creek, the Townsville facility will anchor a pit-toport product manufacturing chain, supplying vanadium flow batteries for global energy storage markets, according to the plans.

Operations are expected to begin in early 2028.

“This investment forms part of our strategy to link international investors with Queensland innovation, by backing projects that leverage our strengths and create more jobs for our regions,” said Dale Last, Queensland’s Minister for Natural Resources and Mines and Minister for Manufacturing.

Mining giant BHP is investing more than AUS$840 million in a series of growth-enabling projects at Olympic Dam, to strengthen the foundations of underground mining productivity and continue building its copper province in the far north of South Australia.

The projects, including an underground access tunnel, a new backfill system, and expansion of ore pass capacity, and those underway elsewhere across Copper SA will improve efficiency and support future growth options of South Australia’s copper province, reinforcing the state’s role as a globally significant supplier, BHP said.

“BHP is the largest producer of copper in the world, and we expect to grow our copper base from 1.7 million tonnes to around 2.5 million tonnes per annum,” said BHP chief operating officer Edgar Basto.

“Achieving that scale requires significant copper growth, and we are fortunate to have a world-class copper province right here in South Australia to do just that.”

Charger Metals has seen its Programme of Works approved for drilling at its Lake Johnston Lithium and Gold Project in Western Australia. This work is being managed by Charger and funded by Rio Tinto Exploration Pty Limited, pursuant to Rio Tinto’s farm-in agreement with Charger in relation to the project. The Company has planned a programme of up to 29-holes for about 4,600 m across six priority lithium targets that have never been drill tested. The remainder of the programme, up to 23 holes, will focus on six priority target areas across the Mt Gordon prospect defined by lithium, gold, and niobium in-soils anomalies and/or structural positions interpreted from geophysics.

Gold has been on an incredible run of late and these stats back it up. It’s also a sizeable indicator that things are starting to improve

has the potential to become a significant producer of spodumene concentrate and contributor to the State’s critical minerals sector, according to Global Lithium Resources.

Rare Earth Deposits

True North Copper Limited said that recent drilling at Wallace North, part of the company’s Cloncurry Copper Project (CCP), has confirmed significant coppergold mineralisation well beyond the current resource boundary, pointing to a substantially larger system

Moreover, the final results from Mt Oxide Phase 1 reverse circulation (RC) drilling program have confirmed the depth persistent, large-scale Aquila copper-cobalt-silver discovery, True North Copper said.

Global Lithium Resources was granted a Mining Lease for its flagship Manna Lithium Project by Western Australia’s Minister for Mines, Petroleum and Exploration for a term of 21 years. The granting of the Mining Lease significantly de-risks the Manna Lithium Project and accelerates its progress towards a Final Investment Decision (FID), following the optimisation of the project’s Definitive Feasibility Study that remains on track for the end of the 2025 calendar year.

The Manna Lithium Project remains the third largest lithium resource in the prolific Eastern Goldfields region, containing a Mineral

Hastings Technology Metals Ltd has completed an agreement with Wyloo Gascoyne Pty Ltd for the development of the Yangibana Rare Earths and Niobium Project. Via an Unincorporated Joint Venture (UJV), the two companies formalised their partnership to progress the Yangibana Project. Wyloo now holds 60 percent of the project and is the UJV Manager and Operator.

“This partnership with Wyloo provides a clear, credible and significantly de-risked pathway to production. It validates the world-class nature of the Yangibana deposit and allows us to unlock the immense value of the project for our shareholders while retaining a meaningful 40% stake,” Hastings CEO Vince Catania said.

Victory Metals Limited has said that recent infill aircore (AC) drilling at its North Stanmore Heavy Rare Earth Element (REE) project in Western Australia has returned some of the highest grades of Dysprosium results ever reported from clay-hosted systems globally. The Dysprosium oxide (Dy2O3) result of 218ppm is about 54 times higher than the Upper Continental Crust (UCC) average of 4.02ppm, Victory Metals said.

“The scale and grade of Dysprosium and Terbium we continue to uncover at North Stanmore is nothing short of extraordinary,” said Brendan Clark, Victory’s CEO and Executive Director.

The company says it is committed to advancing this world-class project to unlock its significant potential.

ABx Group Limited reported “outstanding rare earths extractions” in larger-scale tests conducted for the programme to produce a mixed rare earth carbonate (MREC) at its Deep Leads ionic adsorption clay rare earth project, located 45 km west of Launceston in northern Tasmania. High extraction results were seen for dysprosium (Dy), terbium (Tb), neodymium (Nd), and praseodymium (Pr).

ABx Group says that producing a high-purity MREC from a bulk sample represents a critical milestone for the company in the development of the Deep Leads project.

VHM Limited has received formal approval under the Environment Protection and Biodiversity Conservation Act 1999 for its flagship Goschen Rare Earths and Mineral Sands Project in northwest Victoria.

With the approval secured, VHM will now focus on finalising the Work Plan, finalising strategic off-take agreements and financing, advancing towards a Final Investment Decision, and commencing front-end engineering and design (FEED) studies.

Magnetite Mines Limited has said that nearsurface, clay-hosted Rare Earth Element (REE) mineralisation has been identified at its 100-percent-owned Ironback Hill Project in South Australia’s North-East, adjacent to the company’s large magnetite iron ore deposit.

“We are excited by this early-stage indication of rare earths mineralisation at Ironback Hill and are planning low-cost follow up exploration work to determine if a wider program of work is warranted,” Magnetite Mines managing director Tim Dobson said. 

Resource of 51.6Mt at 1.0% Li2O1. It

APAC Energy Review

By Tsvetana Paraskova

Asia’s dependence on oil imports is rising, but many countries in the Asia Pacific region are looking to diversify their electricity supply away from fossil fuels and boost renewable energy generation

Asia’s Crude Import Dependence Grows

As Asia becomes more and more dependent on oil imports, a fundamental shift in crude flows is under way, Wood Mackenzie analysts said at the annual Asia Pacific Petroleum Conference (APPEC) in September.

For example, in Indonesia, the biggest economy in Southeast Asia, crude oil imports are increasing amid declining domestic production and rising oil demand.

Overall, rising crude demand in Asia’s mostly emerging economies will lead to higher crude oil imports, WoodMac’s oil research and oil trading analysts reckon.

“Our analysis suggests that these imports will have to come from new long-haul sources

to meet the quality requirements for Asian refiners,” they noted.

At the same time, refined product flows are changing rapidly due to structural shortages in key Pacific markets, another key point in WoodMac’s analysis revealed.

Furthermore, refinery maintenance in the fourth quarter is boosting margins for Asian refiners, but these margins could become squeezed again next year, the analysts noted.

In the third quarter of 2025, Asia’s refiners raised utilization rates to seize the strengthening of refining margins, which could be further boosted by heavy refinery maintenance in the fourth quarter.

“However, looking further ahead, lingering supply fears ease; creating the potential for refinery margins to become squeezed once again in 2026,” WoodMac’s analysts said.

Asia’s Low-Carbon Energy Options and Progress

The major US policy shift toward offshore wind, with tax break rollbacks and stop-work orders, could further strengthen China’s dominance in the offshore wind market by the end of the decade, Rystad Energy said in a report in October.

XThe US-China supply chain may be decoupled, but China’s position as a global renewables leader may have only been strengthened because of it.

The energy consultancy expects petrochemicals to play an increasingly important role in future Asian refinery operations, with healthy demand driving investment in specialised units for petrochemical feedstock production.

Integrated sites for petroleum refining and petrochemicals production have outperformed non-integrated sites, with top performers capturing value both from cheap Russian crudes and more robust petrochemical margins.

Operational flexibility has been a key differentiator, with high-performing facilities focusing on petrochemical yields when refined products cracks were weaker, according to Wood Mackenzie’s Refinery Evaluation Model.

Despite the attack on renewables on offshore wind in the US, Rystad Energy research showed that new global offshore wind capacity would reach 16 gigawatts (GW) by the end of 2025, due to projects already underway, with two thirds of them being developed in China.

By 2030, China’s offshore wind projects will claim 45 percent of the world’s cumulative capacity, making it difficult for the US market to compete in the long term, regardless of policy reversals, according to the energy intelligence firm.

“It is now clear that the energy policy shift in the US not only halts or slows progress on offshore wind projects that were previously greenlit but pushes European wind developers away from US investment,” said Alexander Fløtre, senior vice president and head of offshore wind research, Rystad Energy.

“The US-China supply chain may be decoupled, but China’s position as a global renewables leader may have only been strengthened because of it.”

Meanwhile, onshore wind capacity in Southeast Asia could jump from 6.5 GW in 2024 to as much as 26 GW by 2030, driven by a combination of short-term policy initiatives such as auctions, project awards, and attractive feed-in tariffs (FITs), alongside the rising acceptance of mainland Chinese wind turbines, a separate analysis by Rystad Energy showed in October.

Southeast Asia’s onshore wind capacity growth has been mild this decade due to a combination of regulatory hurdles, weak grid infrastructure, high costs associated with developing local supply chains, and persistent reliance on cheaper fossil fuels like coal, which are perceived as more stable.

However, acceleration is under way as nations in the region expand renewables and progress their energy transition goals, according to Rystad Energy.

Vietnam remains the largest market despite policy-driven fluctuations, with the Philippines and Thailand following closely behind.

“Government policies are further boosting momentum, with several new regulations introduced this year to support development,” said Raksit Pattanapitoon, Lead Renewables & Power Analyst, APAC, at Rystad Energy.

With more mature technology, falling equipment costs and improved performance even at lower wind speeds, onshore wind is increasingly a competitive option for meeting renewable energy targets

uneconomic, according to Wood Mackenzie’s new CCUS and Global Power Generation analysis.

The carbon capture costs for European power generators exceed US$300 per tonne, which makes most projects uneconomic, WoodMac says.

“With more mature technology, falling equipment costs and improved performance even at lower wind speeds, onshore wind is increasingly a competitive option for meeting renewable energy targets.”

Asia, where coal is still king, faces challenges in meeting its net-zero targets, but some Asian countries are looking to reduce emissions by turning to ammonia for power generation, particularly through co-firing—blending lowcarbon ammonia with coal or natural gas.

Rystad Energy expects China, Indonesia, Japan, and South Korea to emerge as key hubs for this transition to ammonia use in co-firing. However, a sizeable supply gap remains, with about 8.8 million tonnes per annum (Mtpa) of ammonia needed to meet 2030 targets, according to Rystad Energy’s analysis.

Asian countries appear willing to tackle the challenge of expensive ammonia and advance their co-firing plans, despite the high costs associated with low-carbon hydrogen production, ammonia conversion and transportation, Rystad Energy says.

Costs would be much higher than coal-fired power generation, indicating that costs must be tackled through innovation, economies of scale, or the implementation of a meaningful carbon price to make ammonia co-firing competitive, the intelligence firm reckons.

In carbon capture technology, the economics are in favour of China over Europe, a recent analysis by Wood Mackenzie found.

The global power sector faces a stark divide in carbon capture economics, with Chinese developers claiming dramatic cost advantages while European utilities have to contend with prohibitive expenses that make most projects

At the same time, China claims to build equivalent facilities with CCUS costs of roughly $30-40/tCO2, creating a significant viability gap for the technology across the two regions.

“China’s claimed 70% cost advantage in power plant carbon capture could prove as disruptive to this sector as their dominance in solar manufacturing,” said Peter Findlay, Director and Global Lead, CCUS Economics at Wood Mackenzie.

Smart grids would be critical to meeting the renewable energy surge and the fast-growing energy-intensive sectors, such as data centres, industrial parks, and manufacturing

hubs, in the ASEAN region, think tank Ember said in a report in October.

Smart grids could save ASEAN nations billions of US dollars and unlock clean energy growth, according to the climate think tank.

Ember believes that stronger and more reliable power systems could unlock up to $2.3 billion in annual economic value for ASEAN by 2040.

Smart grid investment of $4 billion to 10.7 billion is needed to modernise ASEAN’s power systems, support economic growth, and enable cleaner, more reliable energy, the report found.

“Smart grids are no longer optional – they are the backbone of ASEAN’s clean energy future. Investing in smart grid infrastructure is both an energy transition enabler and a driver of economic and industrial competitiveness,” said Alnie Demoral, an energy analyst at Ember.

“Modern grids unlock the full value of renewable assets, strengthen industrial growth, and position ASEAN at the forefront of the global green economy.” 

UK North Sea Energy Review

By Tsvetana Paraskova

for our energy future,” the open letter to Chris McDonald, the Minister for Industry at the Department for Business and Trade, says.

The future of the UK tax regime for North Sea operators, the importance of job preservation and creation, and insights into wells and workforce featured as main themes in the UK North Sea oil and gas industry in the past weeks.

“Job losses are occurring at an unacceptable scale, and there is an urgent need for supportive policy to unlock investment, drive economic growth, and safeguard the UK’s energy transition.”

An Offshore Energies UK (OEUK) survey has shown that more than half, 55 percent to be precise, of the UK’s offshore energy firms have reduced their staff headcount in the past year.

The outlook remains challenging, with nearly half, or 45 percent, of surveyed companies expecting to cut jobs further over the next 12 months if the current policy environment continues, according to the latest Offshore Energies UK (OEUK) Pulse Survey.

The survey also reveals a growing trend of companies shifting focus overseas, with one respondent stating: “We’re now actively looking to reduce exposure to the UK energy industry and move operations overseas, reducing UK economic activity and tax take (personal and PAYE).”

“If we allow the decline of North Sea oil and gas to continue unchecked while failing to accelerate renewables, we risk creating a widening gap in jobs, investment and expertise – one that will be felt in communities and industries across the UK,” OEUK Communications Director Natalie Coupar said.

“This isn’t about choosing between energy sources. It’s about securing our energy future by strengthening both oil and gas and renewables.”

The UK Government should avoid accelerating the decline of North Sea oil and gas production through policies, the UK Parliament’s Scottish Affairs Committee said in a report at the end of October.

The committee’s report on the future of Scotland’s oil and gas industry is the conclusion of the first part of its inquiry into GB Energy and the net zero transition.

“The North Sea oil and gas industry has been a vital part of the UK’s and Scotland’s economies but is now at a critical junction as production declines and the UK’s clean energy transition ramps up,” the committee said.

More than 100 UK energy supply chain companies called on the government to reform the Energy Profits Levy (EPL), warning that without a permanent replacement for the tax the nation risks losing thousands more jobs, billions in investment, and critical supply chain capability essential for the UK’s energy security and transition.

OEUK’s Supply Chain Champion, Steve Nicol – Executive President, Operations at Wood, has led a call from more than 110 companies to Government urging them to work with industry and implement a competitive, permanent tax regime from 2026, as outlined in the Treasury’s 2025 oil and gas price mechanism consultation.

“We are witnessing an accelerated decline in activity that is undermining the value of the sector and the supply chain capability we need

Survey participants repeatedly highlighted the EPL as a critical barrier to investment, with one company calling it “the biggest problem we face as an organisation.”

“It’s not just offshore energy firms, our industrial heartlands and their skilled people that need this tax to change – it’s the whole economy,” said Katy Heidenreich, OEUK’s director of supply chain and people.

OEUK also supported the joint letter to the Treasury sent by the British Chambers of Commerce, Aberdeen & Grampian Chamber of Commerce, and the Scottish Chambers of Commerce. The letter emphasises a predictable fiscal regime would send a powerful signal that the UK is once again open for energy investment – unlocking growth, supporting thousands of high-value jobs, and securing billions in future tax revenues, the chambers said.

“The report concludes that reforms to the temporary tax, initially introduced in 2022, should be implemented as soon as possible to create certainty for the industry.”

Patricia Ferguson, Chair of the Scottish Affairs Committee, said, “It’s vital that the government moves quickly to plug this employment gap, replace jobs being lost and ensure a smooth energy transition for workers and communities. Until this is tackled, the government should avoid making decisions that would further accelerate oil and gas production’s decline.”

OEUK’s 2025 Workforce Insight report revealed that the UK could add thousands of jobs, retain economic value, and lead the world in energy with the right policies, collaborative action, and a focus on an integrated energy workforce.

In 2024, about 154,000 people were employed across the UK’s offshore energy sector, including roles in oil and gas, offshore wind, carbon capture and storage (CCS), and emerging technologies.

“With the right policies and investment, the UK can achieve a net addition of jobs, growing the offshore energy workforce from 154,000 today to over 212,000 by 2030, with continued growth in oil and gas playing a central role,” OEUK’s Heidenreich said.

An annual report from the North Sea Transition Authority, Wells Insights, found that well interventions across the UKCS declined from 443 in 2023 to 425 in 2024, continuing a gradual downward trend.

Yet, the interventions that were carried out demonstrated strong results, delivering 37.5 million barrels of oil equivalent (boe) in 2024, equivalent to 34 days of average UK production, the NSTA said in the report. Efficiency also improved, as intervention costs fell from £11 per barrel in 2023 to £9.60 in 2024, while the average Brent crude price was £63.10 per boe, highlighting healthy profit margins for such activity, the regulator noted.

The funding will be split between two workstreams. One will create an enhanced Geospatial Data Viewer which is intended to help users by bringing together datasets from multiple government agencies in one place.

The second workstream will create an AI chatbot to assist users in navigating NSTA’s Open Data and National Data Repository portals, with potential future expansion to other platforms.

With the right policies and investment, the UK can achieve a net addition of jobs, growing the offshore energy workforce from 154,000 today to over 212,000 by 2030

In company news, Vallourec has renewed its longstanding contract with a major North Sea operator to supply OCTG (Oil Country Tubular Goods) products, accessories, and integrated services for offshore operations in the UK North Sea. The multi-year, multimillion-pound agreement reinforces Vallourec’s role as a strategic partner in one of the world’s most technically demanding and cost-sensitive offshore environments, the company said.

P2544 licences, as one of the licence partners, NEO NEXT, has decided to take up its rights of pre-emption.

“While this outcome is of course disappointing, it was always known to be a possibility,” Serica’s CEO Chris Cox stated.

“Serica continues to actively pursue further M&A opportunities, as well as progress our attractive organic growth options, with a goal of diversifying the Company’s portfolio of assets, increasing production, and creating value for shareholders.”

INEOS celebrated in early November 50 years of the Forties Pipeline System, a feat of British engineering that has safely delivered over 9.6 billion barrels of oil and gas. At the same time, INEOS, which earlier this year halted investments in the UK energy sector due to the tax policies, warned that Britain is squandering its energy independence.

Since acquiring the Forties system in 2017, INEOS has invested more than £500 million to modernise and extend its life well into the 2040s, securing one of the UK’s most critical pieces of national infrastructure.

But the NSTA also urged operators to collaborate with the supply chain and unlock cost-efficient production, and keep wells in good shape to sustain production and support suppliers.

There are opportunities to further enhance production by targeting existing fields, as 30 percent of the UKCS’s well stock was shut-in last year.

“While decommissioning will be the next step for many of those wells, a significant number could be reactivated. Without investment, they will be lost permanently, along with domestic reserves and resources,” the NSTA said.

Since early 2024, the NSTA has proactively engaged with eight leading operators to promote interventions and help them identify about 200 shut-in wells which could be reactivated.

“While it is encouraging that some wells have been brought back into production, it is important for all operators to take urgent action by bringing the supply chain into the fold early, putting useful data on the table and making firm commitments to invest in the health of their wells,” said Keith Hogg, NSTA Wells Manager.

The Regulators’ Pioneer Fund has awarded the NSTA a total of £107,000 for a project intended to make North Sea data easier to access

Serica Energy plc has reached an agreement with Finder Energy to buy a 40 percent interest in the P2530 Licence for an initial consideration of about £500,000, or some $650,000. The Licence is currently held by Finder Energy with a 60-percent operated interest and Dana Petroleum with a 40-percent stake. The Licence contains the Wagtail oil discovery and the low-risk Marsh and Bancroft exploration prospects.

Serica, however, suffered a setback in its attempt to buy BP’s stake in the P111 and

However, INEOS warned that “Britain’s ruinous energy policies, including a 78% tax rate, overregulation and political hostility to oil and gas are deterring investment in the North Sea and undermining the nation’s hard-won energy independence.”

Andrew Gardner, CEO INEOS FPS said,

“We should never underestimate the value of home-grown energy. North Sea oil and gas have created enormous prosperity for Britain, and they will remain essential long beyond 2050. Even as we transition to cleaner forms of energy, we will still need reliable domestic supply to power industry, transport, and homes.” 

USA Energy Review

By Tsvetana Paraskova

US oil production is hitting recordhigh levels while the Trump Administration moves to ease energy and power regulations and authorise new LNG export projects.

New Rules to Unleash Industry and Innovation

US Secretary of Energy Chris Wright has directed the Federal Energy Regulatory Commission (FERC) to initiate rulemaking procedures with a proposed rule to rapidly accelerate the interconnection of large loads, including data centres. This would position the United States to lead in AI innovation and in the revitalization of domestic manufacturing.

The proposed rule allows customers to file joint, co-located load and generation interconnection requests. It is also expected to significantly reduce study times and grid upgrade costs, while reducing the time needed for additional generation and power to come online.

Secretary Wright also directed FERC to initiate rulemaking procedures with a proposed rule to remove unnecessary burdens for preliminary hydroelectric power permits. Secretary Wright’s proposed rule clarifies that third parties do not have veto rights over the issuance of preliminary hydroelectric power permits.

“President Trump and Secretary Wright have been clear: The United States is experiencing an unprecedented surge in electricity demand and the United States’ ability to remain at the forefront of technological innovation depends on an affordable, reliable, and secure supply of energy,” the US Department of Energy said.

LNG Project Approvals

At the end of October, Secretary Wright signed the final export authorisation for Venture Global’s CP2 LNG Project in Cameron Parish, Louisiana. The authorisation allows exports of up to 3.96 billion cubic feet per day of U.S. natural gas as liquefied natural gas (LNG) to non-Free Trade Agreement (FTA) countries.

Xclosed in July the $15.1 billion project financing for the first phase of its third project, CP2 LNG, together with the associated CP Express Pipeline. Top exporter Cheniere has made a positive FID for the Corpus Christi Midscale Trains 8 and 9 and Debottlenecking Project. NextDecade has decided to invest $6.7 billion in the expansion of its Rio Grande LNG facility in Texas, in the second Rio Grande expansion announced this year, while Sempra approved a $14 billion Port Arthur LNG Phase 2 expansion.

As a major LNG exporter, the US, alongside Qatar, called on the European Union to significantly amend or rescind proposed corporate climate regulations that include penalties on companies for non-compliance.

President Trump and Secretary Wright have been clear: The United States is experiencing an unprecedented surge in electricity demand...

“Finalizing the non-FTA authorization for CP2 LNG will enable secure and reliable American energy access for our allies and trading partners, while also providing well-paid jobs and economic opportunities at home,” said Kyle Haustveit, Assistant Secretary of the Office of Fossil Energy.

As several LNG export plants ramp up and others are expected to begin commercial operations in the near future, the US is strengthening its global lead as the world’s biggest exporter of liquefied natural gas.

So far this year, Australia’s Woodside has announced the FID for the Louisiana LNG project, with plans to start production in 2029. Venture Global took FID and successfully

US Calls on Europe to Revise Due Diligence Directive

Secretary Wright and Qatari Minister of State for Energy Affairs, Saad Sherida Al-Kaabi, in October sent a letter to the heads of state of EU member states regarding the European Union's proposed Corporate Sustainability Due Diligence Directive (CSDDD).

In the letter, the US and Qatari top energy officials expressed “deep concern over the continued lack of action to address the universally acknowledged, serious, and legitimate concerns raised by the global business community regarding the Corporate Sustainability Due Diligence Directive (CSDDD). Particularly its unintended consequences for LNG export competitiveness and the availability of reliable, affordable energy for EU consumers.”

“We have consistently and transparently communicated how the CSDDD, as it is worded today, poses a significant risk to the affordability and reliability of critical energy supplies for households and businesses across Europe and an existential threat to the future

growth, competitiveness, and resilience of the EU's industrial economy,” the officials wrote.

“It is our genuine belief, as allies and friends of the EU, that the CSDDD will cause considerable harm to the EU and its citizens, as it will lead to higher energy and other commodity prices, and have a chilling effect on investment and trade.”

The EU member states are being urged to either repeal the CSDDD or remove the most economically damaging provisions such as the Directive's extraterritorial application, penalties, and civil liability of companies.

Meanwhile, the Americas LNG Summit & Exhibition in Lake Charles, Louisiana, discussed the economic impact of the US LNG export industry.

LNG projects continue to drive economic growth, workforce opportunities, and responsible development across the US Gulf Coast, panellists including Tim Tarpley, president of the Energy Workforce & Technology Council (EWTC), heard.

US LNG plays a critical role in meeting global energy demand while supporting American jobs, investment, and innovation at home, according to industry leaders.

Speakers highlighted the importance of a strong supply chain and a predictable regulatory environment to keep projects on track and maintain the US position as a trusted energy partner abroad.

EWTC’s Tarpley highlighted the stabilising effect of US LNG exports on domestic manufacturing and gas production, which in turn strengthens the energy workforce and broader economy. Tarpley also emphasised the need for permitting reform to accelerate LNG infrastructure and ensure growth across all US basins. The benefits of LNG extend far beyond individual projects, fuelling opportunity throughout the energy value chain, the executive said.

Industry-Led Effort to Advance Surface Operations Safety

EWTC has also unveiled the Surface Operations Industry Guidelines, developed through the Well Stimulation Committee. These guidelines fill a long-standing gap in the sector by creating a single reference for handling surface operations. Built by people who do the work every day and combining technical knowledge with field experience, the guidelines represent an important step toward consistent, proactive safety practices across the industry, EWTC said.

The industry must take the lead on safety rather than waiting for outside regulation, said Ron Gusek, EWTC Vice Chair and president and CEO of Liberty Energy. Proactive standards like this put the industry in a stronger position and build public trust, Gusek added.

According to John Hutchison, District Manager at ProFrac Services, the guidelines create consistency between service companies and operators by more clearly defining hazard zones and improving communication before operations begin. Early collaboration with operators is key to building safety-focused relationships and ensuring everyone on-site is aligned, Hutchison noted.

Energy Workforce president Tarpley discussed in October the future of global energy with the Greater Houston Partnership and energy leaders from across the industry and government.

US policy must keep pace with market realities, Tarpley said, noting that “We need energy. We need a lot more energy, and that realization is starting to happen in the U.S. and all over the world—on both sides of the political aisle.” 

Secretary of Energy Chris Wright

Middle East Energy Review

By Tsvetana Paraskova

“Regulation without realism and legislation without logic, will only weaken economies, stunt societies and drive capital away,” the executive added.

Flurry of ADNOC Deals

Abu Dhabi hosted in November one of the biggest energy conferences in the world, ADIPEC, at which major UAE companies signed strategic deals and top officials noted the importance of continued investment in global oil and gas exploration and production.

Call for Pragmatic Energy Policies at ADIPEC

Sultan Ahmed Al Jaber, UAE Minister of Industry and Advanced Technology and Managing Director and Group CEO of Abu Dhabi’s national oil company ADNOC, called on energy industry leaders, policy makers, and investors to follow the UAE’s lead and drive pragmatic policies and bold partnerships, to boost job creation, economic growth, and global competitiveness.

Energy and investment policies globally should be “pragmatic, not performative, based on insight, not ideology, built on first principles, not fleeting popularity,” Al Jaber said in his keynote address at the world’s largest energy event, ADIPEC.

“At ADNOC, we are using every technology available, including AI and robotics to collapse time and expand value. Through our homegrown company AIQ, we have embedded over 200 AI use cases, from the wellhead to the trading floor. These tools are cutting unplanned shutdowns by half and enhancing performance across our business,” ADNOC’s top executive said.

Al Jaber also called on the energy industry, policy makers and investors to “tune out the noise, track the signal” as geopolitics shape trade and news flows and sentiment moves markets.

“The signal is telling us that near-term uncertainty is real, while long-term demand remains strong. It is telling us to balance cost discipline with capital investment. Stay laser-focused on efficiency, while investing in people, technology and AI.”

Global annual capital investment needs in grids, data centres and all sources of energy have jumped to $4 trillion because “you can’t run tomorrow’s economy on yesterday’s grid,” Al Jaber noted.

Global electricity demand will keep surging through 2040, as power for data centers surges four-fold, 1.5 billion people will move into cities, and more than 2 billion air conditioners will come online. Aviation will also take off, with the global airline fleet doubling from 25,000 to 50,000 planes by 2040.

“As a result, renewables will more than double by 2040; LNG will grow by 50 percent; jet fuel will increase more than 30 percent and oil will stay above 100 million barrels per day beyond 2040, increasingly used not just for mobility, but more and more for materials,” Al Jaber said.

“What we are really talking about here is energy reinforcement not replacement.”

On the sidelines of ADIPEC, the UAE and ADNOC signed several major deals to power the AI advancement and invest in reliable energy.

ADNOC, Masdar, XRG, and Microsoft in early November announced a strategic agreement to accelerate artificial intelligence (AI) deployment across ADNOC’s value chain, and to deliver energy solutions for Microsoft’s global AI and data centre growth. The collaboration was announced at the ENACT Majlis in Abu Dhabi, ahead of ADIPEC.

Under the agreement, ADNOC and Microsoft will jointly develop and deploy AI agents to drive autonomous operations and unlock greater efficiency, building on ADNOC’s successful deployment of AI solutions across its value chain. Microsoft will also provide advanced AI tools and upskilling programmes, while both companies will explore a joint innovation ecosystem to create transformative solutions for the energy sector.

“As AI continues to reshape how value is created and enhanced across industries, ADNOC, Masdar and XRG are not only embedding AI into every layer of our operations - we are also advancing the energy systems that will power AI itself,” said Al Jaber, who is also executive chairman of XRG and chairman of Masdar.

“Through our partnership with Microsoft, we are unlocking new opportunities to fuel the future of AI, drive greater performance, and future-proof our business.”

ADNOC has also signed three agreements with Gecko Robotics to explore deploying robotics and AI across ADNOC’s operations and boosting future skills training for UAE nationals. The agreements cover a multiyear technology deployment for ADNOC Gas, joint training programmes with the ADNOC Technical Academy (ATA), and the rollout of robotics and AI-powered analytics across ADNOC’s assets to enhance efficiency, reduce downtime and support data-driven maintenance.

“There is a race to lead the AI and energy moment. And the energy companies that win won’t just utilize technology, they will become technology companies,” Gecko Robotics CEO Jake Loosararian said.

“There is only one way to win this race and that’s to acquire physical data using robotics and unlocking human and machine performance from the AI that data fuels.”

ADNOC has also teamed up with top oilfield services provider SLB to use an AI-powered Production System Optimization (AiPSO) platform with initial deployment across eight fields.

Powered by SLB’s Lumi data and AI platform and leveraging Cognite Data Fusion, AiPSO uses millions of real-time data points, AI, and ADNOC proprietary machine learning to proactively monitor and optimize the entire production system, comprising thousands of hydrocarbon wells and hundreds of processing facilities.

The deployment supports ADNOC’s ambition to become the world’s most AI-enabled energy company, the Abu Dhabi firm said.

petrochemical feedstocks. Under the terms of the long-term agreements, which are up to 10 years, TA’ZIZ will supply Sanmar with over 350,000 tonnes per annum of ethylene dichloride (EDC) and vinyl chloride monomer (VCM). The products will be produced at the TA’ZIZ Chemicals Industrial Zone in Al Ruwais Industrial City in Abu Dhabi and represent the first time either chemical has been exported from the UAE.

Production Growth Raises Saudi Aramco’s Profit

Saudi Aramco, the world’s largest oil firm by production and market value, reported solid third-quarter results, with adjusted net income rising slightly compared to a year ago, as higher production offset the impact of lower oil prices.

Aramco’s ability to adapt to new market realities has once again been demonstrated by our strong third quarter performance.

In energy supply, ADNOC has signed a 15-year Sales and Purchase Agreement (SPA) with Shell for the delivery of up to 1 million tons per annum (mtpa) of LNG, ADNOC’s first long-term LNG sales agreement with Shell and the eighth long-term offtake agreement secured for the Ruwais LNG project.

At ADIPEC, TA’ZIZ announced the award of a $1.99 billion Engineering, Procurement and Construction (EPC) contract to China National Chemical Engineering & Construction Corporation Seven, Ltd. (CC7), to build the UAE’s first, and among the top three largest integrated single-site polyvinyl chloride (PVC) production complexes in the world.

TA’ZIZ also announced two product sale agreement term sheets with The Sanmar Group of India, a leading producer of PVC and specialty chemicals, for the supply of key

Saudi Aramco’s adjusted net income inched up to $28.0 billion, up from $27.7 billion for the third quarter of 2024. Cash flow from operating activities and free cash flow also grew by about $1 billion each, to $36.1 billion and $23.6 billion, respectively.

“Aramco’s ability to adapt to new market realities has once again been demonstrated by our strong third quarter performance. We increased production with minimal incremental cost, and reliably supplied the oil, gas and associated products our customers depend on, driving strong financial performance and quarterly earnings growth,” president and CEO Amin Nasser said.

Saudi Arabia’s sovereign wealth fund, the Public Investment Fund (PIF), and Aramco have signed a non-binding term sheet outlining the key terms for Aramco to acquire a significant minority stake in HUMAIN, a

PIF company, advancing a full range of AI capabilities globally.

PIF and Aramco would contribute AI assets, capabilities, and talent into HUMAIN, with PIF and Aramco as its shareholders. PIF would continue to own the majority of HUMAIN. The intention is to enable the rapid scaling up of HUMAIN’s operations to capture value and accelerate its growth in the AI sector.

“Aramco is well positioned to capture opportunities from rising energy demand linked to AI growth, using advanced technologies to improve efficiency, reduce emissions, and sustain our competitive edge as one of the world’s leading integrated energy and chemicals companies,” Nasser said.

In Qatar, state firm QatarEnergy has awarded Samsung C&T Corporation the engineering, procurement, and construction (EPC) contract for a landmark carbon capture and sequestration (CCS) project to serve QatarEnergy’s existing LNG production facilities in Ras Laffan Industrial City.

QatarEnergy has also agreed on a 17-year Sales and Purchase Agreement (SPA) with Indian firm Gujarat State Petroleum Corporation (GSPC) for the supply of up to 1 million tons per annum (MTPA) of LNG to India. Pursuant to the terms of the SPA, the contracted LNG volumes will be delivered exship to terminals in India, starting in 2026.

QatarEnergy has also completed a farm-in transaction with Eni, acquiring a 40-percent participating interest in the North Rafah exploration block offshore Egypt.

The agreement, recently approved by the government of Egypt, grants QatarEnergy a 40-percent stake in the offshore concession, with Eni, as the operator, retaining the remaining 60-percent interest. 

RCP-EDR

ELECTRONIC DRILLING RECORDER

The RCP EDR is designed to give operators a clear, unambiguous overview of critical drilling and mud data processes The system has been developed by RCP to greatly improve how information is presented using the latest industrial technologies and user-friendly interfaces.

The RCP EDR offers a quick and cost-effective solution for clients considering a new installation or a partial upgrade to their existing drilling instrumentation systems Our highly experienced engineers and software developers allows us to tailor each new system to meet your exact needs meaning that you do not pay for functionality you will never use

The RCP EDR utilizes a variety of sensing technologies to monitor the drilling processes, (typically: Level, Pressure, Height, Temperature and Flow). Sensor output signals are received by the distributed I/O racks and are then processed by the EDR.

Processed information is then transmitted through network communication modules to each of the user interfaces including remotely networked PC’s and local HMI’s System and operator interface communications may utilize either: Fibre-Optic, Profinet, Profibus or Industrial Ethernet connection

BRENT OIL PRICES

THE YEARS

1 YEAR AGO

November 2024: Around $74 per barrel, Brent reflected a moderately tight market. OPEC+ maintained production cuts, while resilient U.S. demand and geopolitical uncertainty in the Middle East supported prices. Inflationary pressures and slower European growth tempered optimism. Traders viewed oil as stable but vulnerable to macroeconomic headwinds and shifting supply expectations.

5 YEARS AGO

November 2020: At roughly $43 per barrel, Brent recovered from historic lows earlier that year when COVID-19 crushed demand. Lockdowns and global recession triggered an oil glut, briefly sending futures negative in spring. By late 2020, gradual reopening, vaccine optimism, and coordinated OPEC+ cuts stabilized prices, though uncertainty over recovery remained high.

10 YEARS AGO

November 2015: Brent near $42 per barrel

This reflected a severe downturn. Oversupply from U.S. shale and OPEC’s refusal to cut output drove prices to multi-year lows. Demand growth lagged amid weak global conditions, pressuring energy firms and exporters. The market signaled a long adjustment toward balance after years of abundance and competition.

At the heart of OGV Media Group is the OGV Community, a corporate membership service that connects energy sector organisations with our growing network of professionals, leveraging member engagement and platform traffic to maximize brand exposure.

Subscription to the OGV Community offers its members the following growing list of benefits:

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BUMERANGUE BLOCK

OIL & GAS DISCOVERY

bp has confirmed the presence of a substantial hydrocarbon column of approximately 1,000 metres, including around 100 metres of oil and 900 metres of liquids-rich gas condensate. Planning for appraisal activities is underway, with well operations expected to begin in 2027, subject to regulatory approval. The operator has also indicated that one possible development option for the discovery is an early production system.

VIETNAM GAS PROJECT

PV Drilling has been awarded the drilling contract for the project. The drilling operations are scheduled to take place between March 2027 and August 2027 with 40 development wells expected to be drilled. In addition, Velesto was previously awarded a drilling contract with drilling activities expected to commence in the H1 2026.

BLOCK H FIELD DEVELOPMENT –PHASE 1B

SLB OneSubsea has secured the EPC contract for the SPS scope of the project. The scope of work includes the supply of horizontal subsea trees, umbilicals, control systems and associated services.

SHAH DENIZ COMPRESSION PROJECT

The Saipem and BOS Shelf joint venture has been awarded three offshore contracts worth around $700 million for the SDC project. The contracts cover the transportation and installation of the SDC platform, along with the engineering, procurement, construction, and installation of subsea structures and approximately 26 km of new offshore pipelines linking the SDC platform to existing Shah Deniz infrastructure.

BOURDON OIL DISCOVERY

According to BW Energy, the project’s FID is expected before year-end, but the analyst assumes that sanctioning could be reached by Q1 2026. The project will feature the drilling of three new wells and will utilise the BW Energy Jasmine rig to be converted to a wellhead platform. The discovery’s recoverable resources have been updated to 18MMbbls.

HI FIELD DEVELOPMENT

Halliburton has been awarded an integrated drilling services contract in the project. The company’s project management team will lead execution, and deploy remote operations and automated technologies for the work.

TANGKULO-1 GAS FIELD

The contracting activities for the FEED work and Long Lead Items (LLIs) are still ongoing and remain ahead of schedule. Completion of the PoD is expected in Q4 2025 with FID targeted for June 2026 and first gas anticipated by Q4 2028.

TRION OFFSHORE OIL FIELD

Tenaris will supply casing and tubing for the project, as well as line pipe and casing for bends, flowlines, and risers forming part of the subsea infrastructure. The contract covers 12,000 tonnes of casing and tubing, including 1,600 tonnes made of Super 13 Chrome steel. For the line pipe scope, Tenaris will deliver approximately 16,000 tonnes of pipe for flowlines and risers.

HAMMERHEAD OIL FIELD

Bomesc Offshore Engineering has secured contracts worth up to US$240m to design and build topsides modules for an undisclosed FPSO in Guyana. The work will include chemical skids, electrical rooms, and water treatment systems. Delivery is scheduled between 2026 and 2027, with the topsides module package expected to be completed by June 2027, and the chemical skid, electrical, and water treatment modules by January 2027. Additionally, agreements were signed with ABB and VWS Westgarth, which will be responsible for the electrical systems and sulphate removal water treatment, respectively

Gas

BAB GAS CAP DEVELOPMENT

ADNOC Gas has initiated the bidding process for at least three EPC packages for Bab Gas Cap (BGC). The packages cover early works, onshore pipelines, and process buildings. The project, estimated to aims to enhance gas recovery and condensate production from the Bab field. The project is expected to reach FID in 2026, with completion targeted by 2030.

BUL HANINE OIL FIELD – REDEVELOPMENT –PHASE 2

COOEC has been awarded the EPC contract for the project. The EPC scope covers the engineering, procurement, installation, and commissioning (EPIC) of over 60 offshore oil and gas structures, 40 subsea pipelines and cables, as well as modifications to existing platforms and the decommissioning of outdated facilities. KBR has been awarded a contract for detailed engineering service for the project.

JAZAH GAS AND CONDENSATE DISCOVERY

Kuwait Oil Company (KOC), a subsidiary of Kuwait Petroleum Corporation, has announced a major offshore discovery at the Jazah field. The field delivered the highest vertical well production in Kuwait’s history from the Maqwa formation, producing over 29 million cubic feet of gas and more than 5,000 barrels of condensate per day. Jazah spans 40 square kilometres and holds an estimated 1 trillion cubic feet of natural gas and 120 million barrels of condensate.

Offshore Rising: Marine and Logistics Sectors Ride the Next Energy Wave

The marine and lifting industries are set to benefit from rising investment in offshore oil and gas as producers look to boost resources to meet growing global energy demand.

By Tsvetana Paraskova

The energy logistics market, for its part, has thrived in recent months as oil and LNG exports continue to rise and the number of long-haul voyages increases as energy buyers have to navigate through geopolitical upheavals and sanctions regimes on major oil exporters. The shipping sector is also looking to move to cleaner marine fuels to reduce emissions.

Global Offshore Supply Is Rising

The offshore sector is seen as key to bridging the gap between energy needs and reducing emissions in the energy transition, analysts at Rystad Energy said earlier this year.

Offshore oil and gas development was once poised to be the global leader of supply growth between 2004 and 2012, but the rise and boom of the US shale revolution overshadowed the prospects of offshore oil and gas, said Maierdan Halifu, regional research director for North America.

“Offshore is witnessing a rebirth as competitiveness improves, positioning the sector well for steady future expansion, albeit at a more modest pace than initially anticipated. This resurgence sees Brazil and other basins in the Americas and Africa show strong growth, while East Africa presents significant LNG potential,” Halifu said.

Last year, offshore oil production hit 28.4 million barrels per day (bpd), which was nearly a third of the world’s total output. Offshore gas production was also substantial, hitting about 115 billion cubic feet per day (Bcfd), and accounting for about 30 percent of global gas supply, according to Rystad Energy data. For 2024, the global average of mobile offshore drilling units (MODU) on contract was 550 units (408 units for jackup, 82 for drillship, and 60 for semisub), resulting in a marketed utilisation rate of 88 percent. These three rig types combined drilled about 2,600 offshore wells.

Last year saw one of the lowest volumes of new discoveries in two decades, but a staggering 80 percent of those were made offshore, primarily in deepwater, the intelligence firm said.

Rystad Energy expects deepwater supply to outpace US shale growth in the next few years, Halifu said. The key regions to watch for future offshore crude oil supply are the Gulf of America (Gulf of Mexico), the GuyanaSuriname Basin, Brazil’s pre-salt region with the Santos and Campos Basins, and West Africa, particularly Namibia and Angola.

“These areas have seen significant discoveries and investment and are expected to contribute substantially to global supply,” Halifu noted.

Offshore Contracts Pipeline Remains Strong

Despite headwinds in the global oil industry with an expected oversupply in the near term, the offshore engineering, procurement, construction and installation (EPCI) investment outlook remains strong going forward, analysts at Westwood Global Energy Group said in a recent offshore energy outlook.

After a dip in 2025, offshore oil and gas investment is expected to average $57 billion per year between 2026 and 2029. Offshore wind will continue to dominate EPCI spend, but lower oil prices and inflated supply chain costs are squeezing upstream cash flow and margins, driving a renewed focus on cost control, Westwood reckons.

In offshore oil and gas in particular, National Oil Companies (NOCs) and supermajors now dominate the landscape exploration activity levels.

“To sustain long-term growth, Exploration & Production (E&P) companies may need to diversify – leveraging conventional exploration, accessing discovered resource opportunities (DROs), pursuing M&A, and exploring unconventional plays. This will be crucial as markets continue to favour shortterm returns,” Westwood’s analysts say.

At the same time, rising supply chain costs have delayed some Final Investment Decisions (FIDs) for offshore projects, as operators seek price reductions in response to lower-than-expected oil prices.

But a rebound in FID activity is anticipated in 2026, according to Westwood.

Key growth markets for Offshore Energy Services (OES) between 2025 and 2029 include Saudi Arabia, Qatar, and Brazil, with additional prospects in East and West Africa, Southeast Asia, and the Mediterranean, the analysts noted.

IMO Postpones Adoption of Net-Zero Framework on Marine Fuels

The shipping industry has had to navigate through escalating geopolitical and trade tensions this year while trying to clean up its emissions profile.

In the marine fuels sector, the Marine Environment Protection Committee of the International Maritime Organization (IMO) in October adjourned discussions on the adoption of the Net-Zero Framework for one year, effectively postponing the adoption for another year.

The delay will give member states time to refine ambiguous or contentious elements to produce a stronger, more implementable framework, according to Rystad Energy’s maritime decarbonisation specialists. Rystad Energy’s analysis has revealed critical gaps in the current Net-Zero Framework (NZF) that need to be addressed to ensure an equitable and sustainable transition for the global shipping industry.

Even before the IMO announced it is delaying the framework adoption, Rystad Energy’s research found a substantial disparity between projected clean-fuel availability and targeted demand. This gap, alongside infrastructure constraints, raises doubts that the current timeline to transition to cleaner fuels could be met.

“Decarbonizing the maritime sector is a complex challenge that goes beyond shipping, closely tied to the global shift from fossil fuels to renewables. Our findings suggest progress will likely lag behind the IMO’s current expectations due to infrastructure limits, technology readiness, and energy system interconnections,” said Junlin Yu, vice president of supply chain research at Rystad Energy.

“While the industry is committed, practical constraints demand a realistic approach. The IMO should use the extra year to refine the NZF into a more practical and equitable framework,” Yu added.

Environmental organisation WWF called for work on cleaner shipping to continue despite the delay in the adoption of the framework.

“Even if we’ll have to wait for the Net Zero Framework, there are other measures we can take to slow global warming in the Arctic,” said Elena F. Tracy, Senior Advisor, Sustainable Development at WWF Global Arctic Programme.

For the Arctic, the delay in the adoption of the decarbonisation framework means that the regional-level regulation on reducing black carbon emissions should be considered as soon as possible, according to WWF.

“Cutting black carbon emissions from shipping will result in immediate climate benefits that slow warming in the Arctic and improve public health,” Tracy said.

The next immediate opportunity for goals to cut back on black carbon emissions would be in February 2026, when the IMO’s SubCommittee on Pollution Prevention and Response will meet to discuss polar fuels.

“In the aftermath of the IMO’s delaying the vote on adoption of the Net Zero Framework, we encourage Arctic states to submit concrete proposals on polar fuels that will ensure a reduction in Arctic and near-Arctic black carbon emissions,” WWF’s Tracy said. 

CSIRO and Australian Institute of Marine Science under fire for backing Sea-Dumping agenda

Maritime workers and community members will rally outside CSIRO’s Melbourne office, demanding that Australia’s leading science agencies — CSIRO and the Australian Institute of Marine Science (AIMS) — stop legitimising oil and gas industry research that promotes ocean dumping.

The protest, organised by the Maritime Union of Australia’s member-led Future Jobs Now Committee, calls out CSIRO and AIMS for collaborating with the oil and gas lobby through the National Decommissioning Research Initiative (NDRI).

The union says the research legitimises “in situ” dumping of contaminated steel in the Gippsland Basin, undermining environmental law and costing Victoria thousands of recycling and green-steel jobs.

The MUA also stands in solidarity with CSIRO workers facing job losses and is demanding full funding for independent public science and a clean, worker-led decommissioning industry in Victoria.

Under the guise of “independent science,” the National Decommissioning Research Initiative’s new framework treats in situ decommissioning — abandoning steel and contaminated infrastructure on the seabed —

as an acceptable environmental option, ‘equal or better than full removal’.

In practice, industry funds the work, sets the research agenda, and manages the program, while CSIRO and AIMS lend their institutional legitimacy through participation and co-authorship. The MUA warns that this approach will be used to justify leaving steel pile jackets in the Gippsland Basin, despite the legal standard under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 requiring full removal.

“CSIRO and AIMS are using the credibility of public science to serve private interests,” said Robert Lumsden, MUA Victorian

Branch Secretary. “They’re helping industry rebrand ocean dumping as environmental management. That’s not science — that’s spin.”

The union argues that these frameworks deny Victoria the chance to build a domestic dismantling and recycling industry, with recovered materials feeding the state’s growing green-steel sector.

“Victoria has an electric arc furnace at Laverton that needs scrap steel — exactly what’s being left to rust offshore,” said Aarin Moon, the MUA Victoria Assistant Branch Secretary. “Instead of dumping this material in the ocean, it could power the next generation of clean industry and secure local jobs.”

The MUA is also standing in solidarity with CSIRO workers, hundreds of whom face redundancy due to insufficient federal budget allocations.

“We support the scientists who want to do real, independent research,” said Mr Lumsden.

“But CSIRO’s leadership can’t claim to protect science while cutting jobs and taking oil and gas money. Australia needs properly funded public science — not corporate capture.”

The MUA says Victorian Environment Minister Lily D’Ambrosio has a crucial role in ensuring offshore decommissioning is done properly, as she shares responsibility for the final signoff when oil and gas titles are surrendered back to the public. The union expressed confidence that the Minister understands the stakes — for the environment, the workforce, and future generations.

“Minister D’Ambrosio has shown real leadership on climate and energy,” said Mr Moon. “We’re urging her to bring that same integrity to decommissioning — to make sure companies don’t walk away from their mess and that Victorians aren’t left footing the bill decades from now.”

The union is calling for:

• Immediate withdrawal of CSIRO and AIMS from industry-funded NDRI projects pending an independent review of governance and data integrity.

• Full public disclosure of all oil and gas funding agreements and research veto rights.

• Federal reinvestment in public science and clean manufacturing, linking decommissioning to onshore recycling and green-steel production in Victoria.

Media Quote Sheet

“Victorians are paying attention to the Parliamentary Inquiry because it’s about our coast, our jobs and our future. The last thing we need is CSIRO and AIMS giving cover to the oil and gas lobby’s plan to leave their waste in Bass Strait.”

“The research agenda isn’t neutral — it’s funded and governed by the same corporations that stand to profit from avoiding removal. That’s not independence, it’s buying an outcome.”

“Victoria can lead the clean-up and build a green-steel industry that keeps those materials here in Laverton — or let them rust on the seabed. The inquiry must ensure we choose the first option.”

“This is about what kind of future Victoria wants to build. We can recycle this material into the green steel that powers our renewable future, or abandon it offshore and lose the jobs that go with it.”

“Laverton’s electric arc furnace shows we already have the infrastructure to turn waste into opportunity. That’s what real just transition looks like — Victorian jobs cleaning up Victorian waters.”

“Public science should work for the public. We stand with CSIRO workers who are being laid off, but we’re calling out leadership decisions that sell our science — and our future — to the highest bidder.”

“We built these offshore platforms — we know what’s down there. Leaving them in place is dangerous and short-sighted. It’s not decommissioning, it’s dumping.”

“If the government allows this, future generations will be dealing with mercury, radioactive waste and collapsing structures in our sea. The inquiry must put safety and accountability before corporate savings.”

“The inquiry gives Victoria the chance to draw a line in the sand, we want transparency, independent science and a clear commitment from the Environment Minister: protect the coast, back local jobs and make the polluters pay.”

Key Messages

The Maritime Union of Australia’s Victorian Branch is calling for:

- Full disclosure of CSIRO and AIMS funding ties to the oil and gas industry.

- Withdrawal from industry-led NDRI projects pending independent review.

- State and federal investment in Victorianbased dismantling and recycling, including backing the use of electric arc furnaces.

- Strong recommendations from the Victorian Parliamentary Inquiry to ensure clean-up work creates secure local jobs — not offshore waste. 

THREE60 Energy accelerates Middle East growth with acquisition of Total Vision

Acquisition strengthens THREE60’s presence in the region, anchored by its new UAE headquarters in Abu Dhabi, following record revenue growth and major contract wins.

Abu Dhabi, United Arab Emirates THREE60 Energy, one of the fastest-growing companies in the global energy services sector, has announced a major step in its Middle East growth strategy with the acquisition of Total Vision (TV), a multidisciplinary engineering and project management services provider in Abu Dhabi, United Arab Emirates (UAE).

The acquisition marks a significant milestone in THREE60’s long-term growth strategy, positioning the company to better serve clients across the Middle East’s rapidly evolving energy landscape – from traditional oil and gas projects to emerging sectors such as carbon capture and storage and renewable energy.

The move also strengthens THREE60’s regional footprint following the opening of its new UAE headquarters in Abu Dhabi, which serves as a strategic hub for its expanding portfolio of energy transition and engineering projects across the wider region.

Through the acquisition, THREE60 gains a fully integrated engineering and project management delivery organisation from Total Vision, securing a robust pipeline of ongoing and future projects, alongside deep local

market expertise – providing an immediate platform for accelerated regional integration and growth.

Walter Thain, CEO of THREE60 Energy, said: “This acquisition builds on the foundations we’ve established in the UAE, with Abu Dhabi providing a strong base for our continued growth across the Middle East. It combines Total Vision’s local expertise and reputation with THREE60’s global capability and financial strength, enabling us to deliver broader and more integrated services that further strengthen our position in one of the world’s most dynamic energy markets.

“The Middle East is pivotal to our longterm strategy – a region defined by major investment, industrial diversification, and a clear commitment to wider energy solutions. Deepening our presence here ensures we can support customers across the full energy lifecycle, from traditional oil and gas to renewables and carbon capture.

“In addition, we would like to extend our thanks to Asend Capital, who acted as the exclusive M&A advisor on this transaction.”

Chetan Pathania, Founder and Managing Director of Total Vision, said: “Joining THREE60

Energy marks an exciting new chapter for Total Vision. We share the same commitment to technical excellence, safety, and delivering value to our clients. Becoming part of a global organisation with complementary expertise allows us to expand our capabilities, take on larger and more complex projects, and create greater opportunities for our people and clients across the region.”

The acquisition follows a period of exceptional performance for THREE60. The company has delivered a 36% year-on-year increase in revenue and achieved a number of major contract wins, creating a combined £200 million business with around 1,100 employees worldwide and expanded capabilities across subsurface, wells, subsea, engineering, operations and product solutions.

THREE60’s continued expansion is underpinned by its commitment to innovation, diversification, and sustainability. With the acquisition of Total Vision, the company enhances its regional capability and reinforces its role as a trusted partner for customers navigating both traditional oil and gas and energy transition opportunities in the Middle East. 

Petronas and Eni merger creates new energy player with focus on gas, LNG

NewCo plans to invest more than $15 billion over next five years

Italian energy giant Eni and Malaysian national energy behemoth Petronas on Monday signed a binding agreement to establish a 50:50 joint venture to manage certain key highimpact upstream assets in Indonesia and Malaysia.

The new entity NewCo will manage 14 assets in Indonesia and five in Malaysia. Future plans for the joint venture also include the development of at least eight new projects and the drilling of 15 exploration wells, with the aim of exploiting approximately 3 billion barrels of oil equivalent of discovered reserves and unlocking an estimated 10 billion boe of unrisked exploration potential.

NewCo will operate as a financially selfsufficient entity, expected to be established by 2026, which plans to invest more than $15 billion over the next five years.

“By leveraging existing production assets and developing material initiatives in both the Kutei basin and in Malaysia, we expect to deliver over 500,000 barrels of oil equivalent per day in the mid-term,” commented Eni chief executive Claudio Descalzi.

Upstream earlier reported that initial production from the proposed joint venture is expected to come from Eni’s underdevelopment Kutei North Hub project offshore Indonesia.

“This historic partnership between Petronas and Eni is envisaged to set a new benchmark for more efficient, cost-effective and responsible upstream development,” said Petronas chief executive Tengku Muhammad Taufik.

“Adopting this innovative and proven business model reinforces Petronas’ firm commitment to support national and regional energy aspirations, as it paves the way for us to deliver greater and more sustainable value to our customers, host nations, the greater upstream sector, as well as our stakeholders.”

The joint venture supports both companies’ broader gas aspirations and complements Petronas’ other established businesses in Indonesia outside of the joint venture scope, enabling new opportunities for growth and innovation in the sector, added the Malaysian company.

The co-venturers noted that NewCo would focus on gas projects — both new and existing — including the Kutei basin, an area considered relatively low-risk and high-potential thanks to existing production, transport and liquefaction infrastructure and a mature geological understanding of the subsurface.

Recent milestones include the Geng North discovery and the approval of the Geng North–Gehem integrated development (Northern Hub), both in the Kutei basin.

The assets included in the transaction will retain their current operating set-up, with a strong focus on health, safety and environment, and on time-to-market.

Eni noted the creation of a NewCo with Petronas brings to life a new energy player with a key role in Asia Pacific, particularly in the burgeoning liquefied natural gas market.

Subject to the necessary regulatory approvals in Malaysia, Indonesia and other relevant jurisdictions, as well as partners’ consent requirements and/or pre-emption rights, the new joint venture company is expected to be established in 2026.

The agreement signed on 3 November formalised a process that commenced with a memorandum of understanding in February and the framework agreement that was signed in June during Energy Asia 2025 in Kuala Lumpur.

The NewCo applies the principles of Eni’s satellite model, establishing dedicated, financially self-sufficient entities designed to accelerate industrial growth and value creation — which the company already implemented in previous transactions with Vaar Energi in Norway, Azule Energy in Angola and Ithaca Energy in the UK. 

Rio Tinto appoints Worley to deliver EPCm services for BS1 iron ore project

Worley has been appointed to deliver the engineering, procurement and construction management (EPCm) phase for the Brockman Syncline 1 (BS1) iron ore project in the Pilbara region, Western Australia.

The scope of the EPCm services includes construction of a new primary crusher, overland conveyor, a non-process infrastructure precinct, and a temporary camp for construction workers. The EPCm services will be executed by Worley’s team in Perth with support from Worley’s Global Integrated Delivery (GID) team based in India.

This BS1 project will extend the life of the Brockman region in the West Pilbara of Western Australia. It will have the capacity to

process up to 34 million tonnes per annum (Mtpa) of iron ore, leveraging existing plants with first ore scheduled for 2027.

The EPCm services follows Worley’s delivery of the Definitive Engineering Study phase for BS1 project and continues a trusted relationship between Worley and Rio Tinto that spans 25 years in the Pilbara, including the recent delivery of the Western Range iron ore mine development.

“The continuation of our services for the BS1 project is a testament to our long-standing partnership with Rio Tinto and our proven capability in delivering mining projects in the Pilbara,” said Chris Ashton, Chief Executive Officer of Worley. “We’re pleased to support the EPCm phase of this strategically important project and contribute to the future of iron ore production in Western Australia.”

“The BS1 project builds on the deep technical capability, regional knowledge, and collaborative culture that define how we deliver for Rio Tinto in the Pilbara,” said Andrew Roy, President of Worley Major Projects and Programs – APAC. “We’re further strengthening how we work with Rio Tinto and our delivery partners, bringing greater coordination and working as one team to deliver one goal – the next phase of iron ore production.” 

Moomba CCS receives record Australian Carbon Credit Units after first year of operations

Santos’ Moomba Carbon Capture and Storage (CCS) project has achieved a major milestone for emissions reduction technology in Australia after receiving the single largest issuance of Australian Carbon Credit Units (ACCUs) from the Clean Energy Regulator (CER). The CER confirmed the issuance of 614,133 ACCUs to Santos under the approved CCS method, covering the Moomba CCS project’s initial six months of operations (September 2024 – March 2025).

Moomba CCS passed its first year of operations earlier this month, with the company’s Q3 results[1] reporting 1.3Mt of CO2e safely and permanently stored to date. At full injection rates, Moomba CCS stores more CO2e every four days than 10,000 electric vehicles avoid in one year.[2]

Santos Managing Director and Chief Executive Officer Kevin Gallagher said Moomba CCS demonstrates the real potential for large-scale emissions reduction to be delivered by carbon capture and storage projects in Australia.

Mr Gallagher said, “Policymakers should seize the opportunity to deploy CCS to reduce emissions faster, at scale and cost competitively – particularly when Australia has a unique and natural advantage in carbon capture and storage that is complemented by a well-established, world-class regulatory regime administered by the Clean Energy Regulator.

“Leading global energy research firm, Wood Mackenzie, estimates Australia could unlock up to A$600 billion in revenue by creating a CCS industry and becoming a storage hub for the Asia-Pacific region.[3]

“This is a real industry opportunity for Australia and for South Australia, with Santos seeing interest from customers in both Australia and Asia. It’s a real pathway to green steel and green manufacturing today, and it’s an opportunity to create real jobs of the future that are skilled, well-paid and secure. Moomba CCS is a great example of the just transition in action.

“We have made history out at Moomba. It’s a first for Santos, it’s a first for South Australia and a first for Australia in terms of largescale, onshore CCS. In bringing this project to fruition, I believe we have also started an incredible new chapter in Australia’s energy transition, which could make us a carbon capture and storage superpower.” 

[1] https://www.santos.com/news/2025-third-quarter-report/ [2] Assumes full injection rate of 1.7Mt CO2e per annum. Assumes an intensity of 0.25MtCO2/MWh [DCCEEW National Greenhouse Account Factors 2024] for generation and consumption of 190wh/km [EV-database.org Energy Consumption cheat sheet] for the vehicles. Assumes ICE Vehicle emissions intensity of 200gCO2/km [NTC Carbon Dioxide Emissions Intensity for New Australian Light Vehicles 2021]. Based on 12,100km travelled [ABS Survey of Motor Vehicle Use, Australia]

[3] Wood Mackenzie – Can Australia become APAC’s CCS hub of choice? May 2024 

Finder Energy (ASX:FDR) Signs

Farmout Agreement with Serica Energy for P2530 Licence

Finder Energy to retain operatorship of the licence with Serica Energy taking a 40% stake.

Finder Energy Holdings Limited (ASX:FDR), an Australian oil and gas exploration company focused on creating shareholder value through exploration, appraisal and development of quality assets, has announced a farmout agreement with Serica Energy (UK) Limited. Under the agreement, Serica will acquire a 40% interest in Seaward Production Licence P2530, with Finder retaining a 20% interest and operatorship of the Licence.

The transaction is contingent upon the North Sea Transition Authority (NSTA) extending the Licence term and approving the transfer to Serica, along with other necessary consents. The NSTA has indicated it will grant a ninemonth extension to Phase B, until 31 August 2026, and a twelve-month extension to Phase C, until 31 August 2028. Finder is actively working to fulfil the remaining conditions precedent, with the aim of completing the transaction before the end of the year.

The consideration payable to Finder includes £500,000 (approximately A$1 million) upon completion, a carry of Finder’s share of joint venture costs to the end of Phase B, and £936,000 (approximately A$1.9 million) contingent upon the Licence transitioning to Phase C. P2530 contains the Wagtail Discovery (19 MMbbl Gross 2C Contingent Resources) and the low-risk Marsh and Bancroft exploration prospects.

The extension of Phase B will facilitate additional development engineering feasibility studies to assess the integration of Wagtail with the Triton FPSO and its associated subsea infrastructure. These studies are crucial for determining whether to proceed to Phase C, which would involve drilling an appraisal well on Wagtail, or to discontinue the Licence at the end of Phase B. With Serica joining the P2530 joint venture, both owners of the Triton FPSO will now be partners in P2530 which will facilitate development in the event of a successful appraisal of Wagtail. This announcement has been authorised for release by the CEO of Finder. 

Genus inks new contracts with Fortescue and Western Power

National power and communications infrastructure provider Genus has secured a series of new contract awards with Fortescue and Western Power, reflecting the strength and continuity of its long-standing client partnerships.

National power and communications infrastructure provider Genus has secured a series of new contract awards with Fortescue and Western Power, reflecting the strength and continuity of its long-standing client partnerships.

Rhino

Collectively valued at approximately $135 million, the works highlight the trust Genus has built through consistent performance, collaboration and delivery excellence across Australia’s energy infrastructure sector.

Under its partnership with Fortescue, Genus has been awarded three contracts for the construction of 220kV transmission lines, the design and construction of approximately 30km of overhead power distribution infrastructure at Fortescue’s Christmas Creek mine site and the construction of fast charger and pit power facilities at Eliwana and Flying Fish.

Genus has also secured further works under a variation of its contract with Western Power for the Clean Energy Link North project (CELN), along with a new contract for Network Renewal Underground Power Pilot

Resources extends

project (NRUPP) works. The CELN variation is valued at around $50 million, with the NRUPP contract worth around $25 million, bringing Genus’ total CELN project awards to approximately $390 million to date.

As the company continues to proudly power Australia’s energy transition, these awards reinforce Genus’ reputation as a Tier 1 contractor of choice, one that brings agility, collaboration and de-risking capability to complex energy infrastructure projects.

“These contract extensions highlight the depth of trust and collaboration we’ve built with Fortescue and Western Power,” Genus managing director David Riches said.

“They reflect our ability to de-risk complex projects and deliver with agility and certainty and reinforces Genus as a partner of choice in Australia’s energy transition.” 

Northern Ocean rig campaign off Namibia

John Fredriksen-controlled Northern Ocean, a semisub spin-off of Northern Drilling, has won more work for one of its rigs.

Oil and gas player Rhino Resources opted to amend the contract for the 2018-built Deepsea Mira awarded to the company earlier this year.

Namely, Northern Ocean won a contract in July for one firm well for Rhino, one firm well for another operator, and three optional wells, with an estimated firm duration of 112 days and a projected value of around $40m.

The rig was originally hired to drill the Volans-1X exploration well in Namibia, the third successive well to be drilled on PEL85 by Rhino and its partners NAMCOR, Korres Investments, and Azule Energy. Operations started in mid-July 2025.

Rhino Resources has now decided to incorporate an additional firm well test and extend the rig contract by a total of 28 days. The additional well test will take place before the existing three optional wells.

This extension will increase Northern Drilling’s firm backlog to approximately $394m. 

Tamboran to acquire Falcon Oil & Gas Ltd. to create ~2.9-million-acre Beetaloo Basin business

Tamboran and Falcon Agree to Transformational Beetaloo Basin Combination

Falcon Oil & Gas Ltd. (“Falcon”) and Tamboran Resources Corporation (“Tamboran”) have entered into a definitive agreement to combine their assets and operations, creating a business with approximately 2.9 million net prospective acres across the majority of the Beetaloo depocenter. The transaction represents a significant consolidation within the Beetaloo Basin, bringing together two of its most active participants to form a company with a pro forma market capitalization exceeding US$500 million.

Under the agreement, Tamboran will acquire Falcon through the purchase of all its subsidiaries in exchange for 6,537,503 shares of Tamboran NYSE Common Stock and cash consideration of US$23.7 million. Following completion, Falcon will distribute Tamboran shares to its eligible shareholders at an exchange ratio of 0.00687 Tamboran shares for each Falcon share, giving Falcon shareholders an expected ownership of approximately 26.8% in the combined business. The transaction values Falcon’s subsidiaries at C$239 million (approximately Stg£128 million), representing an implied offer price of C$0.2154 (Stg£0.1152) per share—equivalent to a 19.7% premium to Falcon’s closing share price on the TSX on 29 September 2025 and a 53.2% premium to the 90-day volume-weighted average price.

The combination strengthens Tamboran’s working interest in the Phase 2 Development Area to 80.62% ahead of the company’s planned farmout process, creating greater alignment with Daly Waters Energy, LP (DWE) across exploration permits EP 76, 98, and 117. This follows the recently completed checkerboarding process between Tamboran and DWE. The transaction has received unanimous approval from both the Tamboran and Falcon boards and is expected to close in the first quarter of 2026, subject to customary conditions, including shareholder approvals under applicable Canadian, Australian, and AIM regulations.

On completion, Falcon will cease to own all of its operating assets and will seek shareholder approval to cancel the trading of its shares on both the AIM market of the London Stock Exchange and the TSX Venture Exchange. The subsidiaries being acquired include Falcon’s wholly owned entities in Hungary, Ireland, and South Africa, as well as its 98.1% interest in Falcon Oil & Gas Australia Limited. These subsidiaries reported a combined loss of US$2.2 million and total assets of US$60.7 million for the twelve months ended 31 December 2024.

Falcon CEO Philip O’Quigley said the agreement places Falcon shareholders “at the centre of operations” and gives them “greater exposure to all activities carried out by Tamboran.” He added that it eliminates uncertainty around Falcon’s participation in the Phase 2 farmout process, enhancing shareholder alignment with Tamboran’s strategic development of the Beetaloo.

Tamboran Chairman and Interim CEO Richard Stoneburner described the merger as “a logical consolidation” that will strengthen Tamboran’s acreage position and provide scale across the Beetaloo Basin. With 2.9 million net prospective acres, including a 22.5% non-operating interest in all DWE checkers, Tamboran aims to sell down a portion of its enlarged position to a new farmout partner while maintaining a material working interest.

Upon closing, Falcon’s Board will resign, with Tamboran continuing to be led by Mr. Stoneburner and no planned changes to its current Board of Directors. 

Downer signs deal for works at Chevron’s Gorgon and Wheatstone plants

Australian gas company Senex Energy will supply state-owned utility CS Energy’s planned 400MW Brigalow peaking power plant in Queensland state from 2027, under the state government’s plan to increase gasfired generation in the state.

Downer EDI has won a $750 million Chevron contract for works at the Gorgon and Wheatstone gas exports plants in the Pilbara.

The ASX-listed company was locked in for a term of 10 years starting from January, with a potential five year extension.

The deal will include maintenance, asset management and small capital projects for non-process infrastructure assets at the two LNG plants.

Downer told markets the contract would be worth $750m if it ran the full 15 years.

Chief executive Peter Tompkins said the company had helped improve efficiency at the Chevron facilities.

“This contract builds on a strong, longstanding relationship with Chevron and reinforces our shared focus on keeping our people safe, driving performance, and collaboration,” he said.

Mr Tompkins also pledged that the two companies would create “meaningful opportunities for local and Indigenous communities”.

The Gorgon and Wheatstone plants ship almost 25 million tonnes of liquefied gas annually between them to trading partners including Japan and South Korea.

Chevron’s two facilities also produce more than 40 per cent of Western Australia’s domestic gas.

The West Australian reported in October that drilling on the company’s next wave of offshore fields — Geryon and Eurytion — was expected to get under way next year. 

bp award THREE60 Energy and AF Gruppen Andrew decommissioning project in the UK

A new joint venture (JV) between THREE60 Energy (THREE60) and AF Offshore Decom (AFOD), a subsidiary of AF Gruppen, has been awarded a multi-million-pound contract by bp to provide integrated decommissioning services for their Andrew field in the North Sea.

A first of its kind in the UKCS, this contract will see the joint venture assume the role of decommissioning services partner. The JV will deliver post cessation of production (CoP) operations, well decommissioning, facilities / pipelines / topsides preparation, substructure and topsides disposal and subsea infrastructure removal. The JV will also work alongside the topsides removal contractor to ensure successful unified delivery of the full decommissioning scope.

The contract, which is subject to regulatory approvals, will be delivered over several phases, with the initial phase being well planning, P&A preparation scopes, including platform readiness, and transition planning.

Within the JV, THREE60 will combine its responsibility and capability as Installation, Pipeline and Well operator with AF Offshore Decom’s experience and track record in EPRD preparation, management and disposal.

THREE60 is a leading independent energy service company offering complete asset life cycle solutions. Their engineering, subsea, operations and wells team will leverage its differentiated and previous experience as Duty Holder, Pipeline Operator and Well Operator to deliver this integrated scope.

For over 20 years, AFOD has been a dedicated decommissioning EPRD main contractor in the North Sea. The company has safely prepared, removed, and recycled more than 90 offshore structures and has built extensive experience in managing large and complex projects. The company also operates a purpose-built decommissioning facility; AF Environmental Base Vats. Their deep breadth of offshore experience in project delivery, EPRD management and execution, as well

pure disposal, will be integrated into the project team.

The Andrew field is located 225km northeast of Aberdeen and serves as a central hub for four subsea fields. The facility features a steel structure that integrates both drilling and production facilities, with the topsides weighing approximately 11,100 tonnes and the supporting structure around 7,600 tonnes. The Andrew area includes 17 platform wells, 8 subsea wells, 41km of subsea bundles, 42km of umbilicals, and 2,500 tonnes of subsea equipment.

Walter Thain, Group CEO of THREE60, commented on the contract award: “We are honoured to partner with AF Offshore Decom on this significant bp project. The award is testament to both our team’s collective work throughout the tender process and in co-creating a bespoke solution to meet bp’s requirements. We are dedicated to delivering comprehensive and safe decommissioning solutions and really excited to embark on this journey.”

Alice Andreassen, Managing Director in AFOD said: “We have found the right partner who complements our vision of delivering across the entire value chain. In this partnership, AFOD will integrate with THREE60 to deliver integrated decommissioning solutions in compliance with bp requirements. We are really looking forward to embarking on this journey together with THREE60, to deliver this important project with bp. This partnership is strategically important for the North Sea market and the future of decommissioning project execution models.”

The scope of work will be delivered from a THREE60 – AF project office headquartered in central Aberdeen, Scotland. 

Allseas wins UK North Sea decommissioning

job

Operator Taqa UK is in process of decommissioning Brae Alpha platform in North Sea

A major contract has been awarded for the decommissioning of topsides at the Brae Alpha platform in the UK North Sea.

Operator Taqa UK has picked offshore contractor Allseas to carry out engineering, preparation, removal and disposal (EPRD) of the Brae Alpha topsides, following a competitive tender process.

The work is scheduled to begin later this year and will be a key part of one of the UK’s largest decommissioning programmes.

Allseas will deploy heavy-lift vessel Pioneering Spirit to remove the 33,000-tonne topsides and 12,000-tonne upper jacket, in two standalone campaigns.

Sandy Hutchison, managing firector of Taqa UK, said the work “represents a major project for a platform that has played a significant role in the UK’s energy security over four decades”.

Taqa has committed to reusing or recycling at least 95% of recovered topsides material.

Located around 270 kilometres northeast of Aberdeen, Brae Alpha began production in 1983. It has produced over 636 million barrels of oil equivalent during its lifetime.

Allseas is also carrying out the EPRD programme for Taqa UK’s North Cormorant, Tern, Eider and Cormorant Alpha assets in the North Sea as part of the largest single offshore decommissioning contract awarded in the UK to date. 

DeepOcean engaged for Western Australian decommissioning project

Ocean services provider DeepOcean has been appointed to support the decommissioning of subsea infrastructure at oil and gas fields in Western Australia.

DeepOcean’s scope of work includes suspension of subsea trees, removal of flowlines, riser and dynamic umbilical, and removal of a disconnectable turret-mooring buoy (DTM). The work is scheduled for 2026 and will be performed from one of the company’s regional vessels. The fields are off the coast of Western Australia, in water depths between 300-400 metres. DeepOcean will manage the project out of its office in Perth, Australia.

“We are honoured that DeepOcean has been entrusted with the delivery of this significant project. It builds on our extensive regional and international experience in decommissioning and reinforces our long-term commitment to supporting the energy sector in Australia,” says Colin McGinnis, managing director of DeepOcean’s Asia Pacific operation.

Earlier this year, DeepOcean acquired Shelf Subsea – an independent provider of subsea services with a strong position in the eastern hemisphere, including Australia. Founded on a robust industrial fit, the acquisition created a global subsea services player with an extensive portfolio of solutions, covering the Asia-Pacific and Middle East regions too through Shelf Subsea.

“DeepOcean is already one of the market leaders within subsea decommissioning in the mature North Sea region. This project demonstrates that we are already managing to combine the local Shelf Subsea expertise with our North Sea decommissioning competence. The end-beneficiary is our clients in the region,” adds Colin McGinnis.

DeepOcean has not disclosed the value of the contract. 

are a leading independent energy service company offering complete asset life cycle expertise.

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Building Trust in International Markets:

How ATPI’s People-First Duty of Care Approach Gives Companies the Confidence to Deploy Staff

Safely Across Borders

Successful international expansion depends on one crucial factor: the ability to move people confidently and safely across borders. In today’s complex geopolitical environment, ensuring that employees can travel and work securely is essential for sustaining global growth.

ATPI’s people-first duty of care approach gives organisations the confidence to deploy teams worldwide, even in challenging markets such as the Middle East. With safety, wellbeing, and support embedded into every aspect of travel management, ATPI empowers companies to focus on growth while knowing their people are protected.

A People-First Approach to Global Mobility

At the heart of ATPI’s global success lies its commitment to people. Whether deploying engineers to remote energy sites or coordinating large-scale crew rotations across continents, the company’s top priority is always the safety, wellbeing, and efficiency of travellers.

For ATPI, duty of care isn’t a policy — it’s a mindset. Every travel request, decision, and communication is guided by a proactive approach to risk management and traveller support. By combining risk intelligence, travel management, and local assistance, ATPI ensures that every traveller is informed, protected, and connected, no matter where their journey takes them.

This integrated model not only reduces risk exposure but also builds long-term trust between ATPI and its clients, giving organisations the assurance they need to expand confidently into high-growth, high-potential regions.

Global Reach, Local Expertise

ATPI’s global presence is underpinned by teams on the ground in every energy major region. This structure allows the company to deliver real-time updates, instant crisis response, and 24/7 in-house support, thus ensuring that operations continue seamlessly, even in the most challenging circumstances.

The ability to mobilise teams quickly, share intelligence instantly, and coordinate centrally gives clients peace of mind that their people, and their business are in safe hands.

Strength in Partnership: A Strategic Presence in Saudi Arabia

A cornerstone of ATPI’s Middle East operations is its joint venture in Saudi Arabia, which provides unrivalled local expertise and operational agility. This partnership strengthens ATPI’s ability to navigate the region’s evolving regulatory landscape, manage complex cross-border movements, and offer in-person support when it matters most.

For clients, it translates into smoother operations, faster response times, and trusted local insight, which provides critical advantages when doing business in a dynamic and rapidly growing market.

Confidence to Expand, Backed by Care

As organisations continue to pursue opportunities in emerging and high-growth markets, having a trusted global travel partner that prioritises people above all else has never been more vital.

ATPI’s people-first duty of care approach is more than a promise, it’s a proven strategy that enables companies to operate globally with confidence, knowing that their most important asset, their people, are supported every step of the way.

Case Study: Navigating Complex Crew Mobilisation Amid Airspace Disruptions

When sudden airspace closures in the Middle East disrupted commercial flight paths, ATPI faced the challenge of rerouting 120 crew members travelling between Erbil and Sulaymaniyah in Northern Iraq, ensuring safety and minimal delays.

With volatile airspace conditions, ATPI swiftly executed and coordinated a mobilisation plan. Mardin Airport in Turkey was designated as an alternate hub, supported by cross-border ground transfers and customs coordination. Manual hotel bookings, tailored catering, and bank transfer payments were managed precisely. Crews received layover support in Istanbul, while dynamic monitoring ensured rapid response to flight changes.

As a result, ATPI safely rerouted all 120 crew members, maintaining 100% invoice accuracy, and achieving zero escalation requirements. The operation demonstrated exceptional teamwork, precision, and resilience under pressure, earning high praise from the client’s Iraq-based teams.

Delivering Confidence Through Experience

This case underscores how ATPI’s global reach, local expertise, and people-first philosophy combine to deliver real-world results. From proactive crisis management to 24/7 operational support, ATPI empowers organisations to send their teams anywhere in the world with complete confidence.

In markets like the Middle East where success depends on agility, reliability, and trust, ATPI stands as a partner that not only moves people safely but keeps businesses moving forward. 

If you would like to find out how ATPI can help streamline your travel management, email: atpienergytravel@atpi.com

Zara Higgins, General Manager Saudi Arabia / Head of Energy – Arjaa ATPI