OGV Energy Australia - Issue 1 by OGV Energy

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Offshore service offerings include Wellhead Maintenance and Well Integrity Management, covering Annulus Top-Ups, X-Tree Removal, Valve Refurbishment, Digital Pressure Services, Ecometers, Sealants, and HP Pump Units with Accessories.

Wellvene supports the global energy market by designing, manufacturing and qualifying bespoke, quality-assured equipment well completion, intervention, integrity & P&A operations.

Engineered Well Solutions solutions for a wide range completion, intervention, and operations.

Flow Control Solutions

Offering a variety of landing nipples, profile plugs, and equalising devices to suit new and existing OEM profiles.

Safety Valve Remedial Services

A single-source solution to reinstate DHSV functionality and production within a single well campaign.

Intervention Services

deployment methods for slickline, e-line, and DSL intervention operations.

Plug and Abandonment Services

Delivering safe and efficient well P&A tool packages and bespoke solutions for ageing well stock.

A WORD FROM OUR EDITOR

DHVI:

Camera and Caliper Inspection

Happy New Year and welcome to the inaugural issue of the OGV Energy Australia Magazine 'Well Management and Subsea'

Equipping you with a clear and accurate visualisation of your wellbore, we help you identify and solve issues faster.

I'm delighted to be heading up the new Australian arm of OGV Energy and look forward to be bringing you the latest industry news and content from all over Australia, wider APAC region and across the globe.

Thank you to Elemental Energy and Archer for a review of their joint venture and what that means for the Australian sector. For more please turn to our feature article on page 4.

We are delighted to showcase contributions in this month's edition from Destec, Lokring, Cegal, Wellvene, Rotech and many others. As always, this issue also provides a thorough review of the energy sector across Australia, the North Sea, Europe, the Middle East, and the USA.

You'll also find insightful articles from Brodies LLP and Leyton, as well as updated industry analysis and project updates from Westwood Global Energy Group and the EIC.

We hope you enjoy the first issue of 2025!

Emma Davidson

Elemental Energies and Archer Join Forces for Global P&A Joint Venture

Elemental Energies, a leading specialist in well engineering, subsurface, and project management, has partnered with Archer, a global drilling and well services expert, to launch a joint venture (JV) delivering integrated plugging and abandonment (P&A) services for decommissioning projects worldwide. This partnership formalises years of successful collaboration, setting a new standard for P&A operations.

The JV combines Elemental Energies’ proven track record in managing over 700 wells— including 210 deepwater projects and 500 decommissioning operations—with Archer’s world-class well services technology and operational reach. With more than five decades of industry experience and a presence in over 40 countries, Archer’s 5,000-strong team enhances the JV’s ability to drive project efficiency while reducing costs for operators.

Boosting P&A Efficiency for Australian Operators

The JV offers operators a fully integrated approach to well abandonment, covering both platform and subsea projects. Combining

Elemental Energies’ subsurface and project management expertise with Archer’s cuttingedge P&A technologies, the JV delivers streamlined project execution, enhanced oversight, and cost reductions.

Australian operators can benefit from tailored services, spanning from project planning to final execution. The JV’s dedicated team works closely with clients to adopt best-inclass P&A methods that maximise operational performance while supporting environmental sustainability. Recognising that operators require flexible options, the JV provides both integrated and standalone services, enabling operators to choose the best approach for their specific decommissioning needs.

Supporting Australia’s Growing Decommissioning Market

This partnership comes at a time when Australia’s offshore energy sector is experiencing significant growth. The recent Australia-UK Offshore Decommissioning Cooperation highlights the importance of international collaboration in shaping a sustainable future for the energy industry.

The agreement links the UK’s decades of North Sea decommissioning expertise with Australia’s expanding offshore services market. A working group comprising industry leaders, regulatory bodies, and academic partners has been established to drive best practices, facilitate knowledge transfer, and identify priority decommissioning projects that would benefit from international cooperation.

Elemental Energies brings over 35 years of operational experience and a history of strategic acquisitions, including Senergy Wells, Norwell Engineering, and Norway-based Well Expertise. These moves have strengthened its capabilities across exploration, field development, decommissioning, and emerging sectors such as carbon capture, utilisation, storage (CCUS), as well as geothermal energy—all areas relevant to Australia’s energy future.

Similarly, Archer has expanded its global capabilities through acquisitions like Wellbore Fishing & Rental Tools, enhancing its specialised P&A and fishing services portfolio. With a focus on drilling, well services, and renewables—including geothermal, carbon storage, and offshore wind—Archer’s expertise positions the JV as a major force in the international P&A market, well-suited to support Australia’s evolving decommissioning landscape.

Driving Innovation and Sustainability in Australia

The JV’s goals go beyond operational efficiency and cost reduction. Its long-term vision includes advancing P&A technology while supporting Australia’s decarbonisation and sustainability goals. By improving project design and execution, the partnership aims to minimise the environmental impact of decommissioning projects.

With innovation and sustainability at its core, the JV is poised to deliver customised, efficient solutions for Australian operators. As Elemental Energies and Archer continue to expand globally, the JV sets a benchmark for well decommissioning excellence. Its collaborative approach supports Australia’s energy transition and strengthens its offshore energy capabilities. 

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Design

Editorial

COMMUNITY news

ANYbotics and Createc

Collaborate to Revolutionize Nuclear Facility Inspections

ANYbotics, a leader in autonomous mobile robotics, has collaborated with Createc, a specialist in robotic applications for nuclear decommissioning, to transform the nuclear industry through advanced robotic inspections. This collaboration will improve accuracy, streamline workflows, and provide integrated robotics and radiation detection solutions. Together, they will set new standards for inspecting nuclear facilities, reducing risks and costs while driving innovation.

Critical Nuclear Inspections Ensure Safety and Efficiency

Inspections in the nuclear industry are critical to ensuring safety, regulatory compliance, and operational efficiency. They play a crucial role in identifying potential risks, such as equipment fatigue or radiation leaks, before they escalate into serious accidents and protect workers and the environment.

DRIFT Offshore and Kystdesign collaboration addresses skills shortfall

Subsea resourcing specialist DRIFT Offshore, which provides people and expert support services for projects internationally, has entered a partnership with Norwegian ROV specialist Kystdesign to strengthen the service offering of both businesses.

The collaboration aims to enhance both companies’ service offerings by focusing on specialist pilot training for Kystdesign’s advanced ROV systems, addressing critical skills and training needs in the subsea industry.

DRIFT Offshore’s experienced personnel, recognised for their expertise in underwater robotics, have been certified as official ROV pilot training partners for Kystdesign’s systems.

CyberPrism strengthens market position amid rising threats to critical infrastructure

CyberPrism, a leading provider of OT cyber security solutions, is proud to report significant growth over the past year, driven by increasing awareness of cyber risks among energy operators and a surge in demand for robust security measures.

As a result of rising demand, a series of major contract awards with four North Sea operators has been central to the company’s expansion over the last year.

Those contracts have seen CyberPrism engage with clients to enhance the safety and security of their energy-producing assets across the UKCS. These include assessing cyber risk, instituting governance and management systems, generating OT cyber security policies, conducting detailed platform risk assessments and providing regulatory compliance support.

Serica Energy plc – Acquisition of assets from Parkmead Group

Serica Energy plc announces that it has signed an agreement to acquire 100% of the shares in Parkmead (E&P) Limited (‘PUK’) from Parkmead Group Plc (‘Parkmead’), which includes a 50% working interest in licence P2400 (Skerryvore) and a 50% working interest in licence P2634 (Fynn Beauly), for an initial consideration of £5 million ($6.4 million1).

An additional deferred consideration of £9 million ($11.5 million1) will be paid in stages over the next three years, as well as contingent payments linked to certain development milestones – payable on receipt by Serica of approval by the North Sea Transition Authority (‘NSTA’) for a field development plan (‘FDP’) relating to Skerryvore or Fynn Beauly.

Vårgrønn and Flotation Energy Award FEED Contracts, Advancing Pioneering Green Volt Floating Wind Project

Green Volt set to unlock £2.5 billion of private investment and create up to 2,800 jobs

16 December 2024: The pioneering floating offshore windfarm Green Volt, based off the Northeast coast of Scotland, has awarded front-end engineering and design (FEED) Phase 1 contracts to two sets of leading engineering companies:

• Aker Solutions and ABB

• Aibel and Hitachi Energy

Green Volt, which will be located 80 miles off the Scottish coast, was successful in winning a UK Government Contract for Difference (CfD) in September this year and is the first major commercial floating wind development in Europe. The CfD puts it on track to become the world’s largest floating offshore windfarm with a government contract.

OEG continues expansion plans with new global HQ in Aberdeen

OEG Energy Group Limited (“OEG”, the “Group”), a leading energy solutions business, has moved into a new global HQ at The Stratus Building, ABZ Business Park in Dyce, Aberdeen, following a sevenfigure sum investment in a multi-year lease. This marks a significant milestone in the organisation’s 50-year journey, underscoring its deep commitment to its local roots while serving as a launchpad for its ambitious global expansion in renewables and other key offshore energy markets.

The high-specification 1,541 sq. m (16,591 sq. ft) office can accommodate up to 100 personnel across three floors. OEG’s previous corporate office in Kintore (Aberdeenshire), will continue as an operational hub with room to accommodate future growth.

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Australia Energy Review

By Tsvetana Paraskova

As Australia seeks to lead global climate partnerships, it is boosting the development of renewable energy projects, while oil and gas operators in the country plan to add more to natural gas and LNG supply to one of the biggest exporters of liquefied natural gas in the world.

Gas Supply Boost

ExxonMobil’s unit Esso Australia Pty Ltd, the operator of the Gippsland Basin Joint Venture, announced in October it had safely completed the Kipper Compression Project, maintaining crucial natural gas supplies for the domestic market.

The Gippsland Basin Joint Venture is a 50-50 joint venture between Esso Australia Resources Pty Ltd and Woodside Energy Pty Ltd.

The project required the installation of compression facilities on the West Tuna platform in order to maintain production from the Kipper field, which experiences decreasing reservoir pressure as it depletes.

“Accessing new gas supplies or maintaining gas production is not simply a matter of flicking a switch; our project and operations teams put in more than one million hours to ensure its safe completion and on schedule,” said ExxonMobil Australia Chair, Simon Younger.

As the Federal Government notes, natural gas remains a crucial part of the energy grid as a vital backup to renewables, and will also be key for industries such as glass, bricks, steel, fertiliser, recycling and critical minerals that don’t have alternative energy or feedstock sources, Younger added.

In another boost to gas supplies, Australia’s energy company Santos has said that its Barossa Gas project is now over 82 percent complete and remains on track for production in the third quarter of 2025.

Barossa Gas Project is an offshore gas and condensate project that proposes to provide a new source of gas to the existing Darwin liquefied natural gas (DLNG) facility in the Northern Territory.

Santos also completed commissioning at its Moomba Carbon Capture and Storage (CCS) project, which is now online and storing CO2 in Cooper Basin depleted reservoirs at full rate.

In November, Santos announced a carbon storage growth target to build and operate a commercial carbon storage business that would permanently store approximately 14 million tonnes of third-party CO2e per annum by 2040.

“The successful startup of Santos’ 1.7 million tonnes per annum Moomba Carbon Capture and Storage (CCS) project last month, with the technology and reservoirs performing as expected, demonstrates the potential for future phases to provide safe, low-cost, permanent carbon storage for customers and hard-toabate industries,” the company said.

Santos has advantage in the race for LNG supply to Asia, thanks to geographical proximity, Managing Director and CEO Kevin Gallagher said.

“The market outlook for LNG into Asia, domestic gas in Australia and liquids remains strong out to 2040 and beyond,” Gallagher added.

Separately, Santos has also announced that the Darwin LNG joint venture operated by Santos had achieved financial close of new syndicated bank loan facilities totalling US$800 million, to fund life extension works.

“With these facilities in place, Darwin LNG is

well-funded to complete the life extension works scheduled for mid-2025 and it positions Darwin LNG to consider future expansion of this important infrastructure, including through the potential provision of third-party carbon capture services in Darwin,” Gallagher said in October.

Another Australia-based energy major, Woodside, has completed the sale of a 15.1-percent non-operating participating interest in the Scarborough Joint Venture to JERA, Japan’s largest power generation company.

The Scarborough field is located approximately 375 km off the coast of Karratha, Western Australia, and the reservoir contains less than 0.1 percent carbon dioxide. Scarborough gas will be processed at the Pluto LNG facility, where Woodside is currently constructing Pluto Train 2. As of 30 September 2024, the Scarborough Energy Project was 73 percent complete, Woodside said.

“In addition to supplying markets in north Asia the project will be an important source of gas for the domestic market in Western Australia,” said Woodside CEO Meg O’Neill.

“The team is delivering the Scarborough Energy Project to plan and work is now almost three quarters complete. We remain on track for targeted first LNG cargo in 2026.”

In November, Woodside said it had awarded its largest-ever Traditional Owner construction contract to Karratha company Winyama Contracting Group for the delivery of civil works for the Pluto Train 1 Modifications project.

Winyama Contracting Group will be working alongside Kellogg Brown & Root Pty Ltd, Woodside’s Engineering Procurement and Construction Management contractor for the project. The decision to award to Winyama Contracting Group followed a commercially competitive bid process based on criteria including experience, local content, and HSE performance.

Australia-UK Energy and Climate Partnership

While continuing to bet on natural gas, Australia also looks to lead in emissions reduction and climate partnerships globally.

Australia and the UK signed in November a new climate and energy partnership at the Conference of the Parties (COP29) United Nations climate summit in Baku, Azerbaijan.

The Australia-UK Climate and Energy Partnership reflects the countries’ shared ambition to act on climate change and play significant roles in the global clean energy transition.

This partnership replaces the existing technology partnership from 2021, reflecting the increased ambition for climate action by both Australia and the UK.

Through the Partnership, Australia and the UK will focus on two key areas. One is net zero technology cooperation, including in tech for hydrogen, offshore wind, energy storage, and clean transport. The countries will also work on creating common standards for these technologies, so they can be used worldwide in a more efficient way.

The other priority of the Partnership will be international climate cooperation to coordinate global climate action under the Paris agreement through key multilateral groupings, including the G20, the IEA, as well as the UNFCCC to drive global climate ambition.

Accelerating Renewables

At the end of November, the Albanese Government pressed go on the Future Made in Australia (Guarantee of Origin) Bill 2024 and its two supporting bills, which establish the voluntary Guarantee of Origin (GO) scheme. This is an Australian Governmentbacked certification scheme to authenticate low-emissions products and support renewable electricity.

The scheme is expected to help Australian producers remain competitive in new and emerging domestic and global markets by accounting for and accurately presenting the low-emissions reality of their products. It will provide Australian businesses and investors with the regulatory certainty to support and encourage investment through a highintegrity certificate scheme that makes sure that renewable energy and decarbonised products can be properly valued.

“The GO Scheme is a key element of the energy transition toolbox that our government is putting to work to drive investment as we strive to become a renewable energy superpower,” said Chris Bowen, Minister for Climate Change and Energy.

Meanwhile, investment commitments in new generation projects in Australia continue to trend upwards, with more than 1,400 megawatts (MW) of new large-scale renewable energy generation projects, worth AUS$3.3 billion in new investment, committed in the third quarter of 2024, the Clean Energy Council’s latest Quarterly Renewables Report showed.

One of the highlights of the new investment data is the rebound in onshore wind projects, with 1,758 MW of new capacity committed so far in 2024.

Investment committed in energy storage projects also continued to grow, with eight projects setting a new 12-month quarterly average record with 1,235 MW of new capacity (3,862 MWh of energy output) reaching financial commitment – a 95 percent surge compared to the same period of 2023.

The third quarter showed the healthiest investment data for new renewable energy generation projects since late 2022, Clean Energy Council Chief Executive, Kane Thornton, said, indicating that conditions were gradually improving for the sector.

“The increasing activity indicates that the challenging economic conditions are beginning to ease and the hard work by government agencies and industry to address a wide range of legacy issues across our grid, planning and institutional settings, are starting to bear fruit,” Thornton said.

“If we sustain the level of investment for new wind and solar power plants which we have seen in the third quarter of this year, we can get back on track to achieving Australia’s target of 82 per cent renewable energy generation by 2030.”

In major project news, an international consortium of companies has submitted to Western Australia’s Environmental Protection Authority (EPA) the Western Green Energy Hub (WGEH), a 70-gigawatt (GW) project planned to include large-scale wind and solar

power to produce value added products, with the base case assuming green ammonia production.

The proposal is situated on WA Mirning Native Title determined land in the far southeast of Western Australia. The consortium plans to install up to 60 million PV panels across 35 solar farms and up to 3,000 wind turbines, each ranging from 7 MW to 20 MW.

Meanwhile, the Western Australia government unveiled at the end of October its renewable hydrogen strategy. The new plan, WA’s Renewable Hydrogen Strategy 2024–2030, is a comprehensive update of the previous strategy, and targets to have renewable hydrogen production begin at scale in Western Australia by 2030. The state’s government also aims to have secured an off-take agreement for renewable hydrogen products for international export by 2030.

In another Australian state, New South Wales, the government has developed a new Renewable Energy Planning Framework to promote faster planning decisions, provide investment certainty for industry and host communities, and boost economic benefits for regional communities.

The Framework introduces setbacks to avoid significant visual impacts from wind energy and transmission infrastructure, updates requirements for assessing hypothetical dwellings, and establishes the Government’s expectations for how benefits from renewable energy projects will flow directly to regions.

The Clean Energy Council welcomed the new guidelines, which “will play a crucial role in ensuring wind and solar farms in NSW are assessed in a timely manner, helping the state to maintain a reliable electricity supply,” said Dr Nicholas Aberle, Clean Energy Council Policy Director – Energy Generation & Storage.

“NSW needs to build almost 2 GW of wind and solar projects each year to be on track to meet its state targets and just over 3 GW per year to meet Federal targets,” Aberle said.

“Getting enough projects built depends on getting enough projects approved, so it is critical that planning processes are well-designed and well-implemented.” 

UK

North Sea Energy Review

By Tsvetana Paraskova

The state of the UK offshore decommissioning and technology innovation and a major merger deal were the highlights of the UK North Sea oil and gas industry at the end of 2024.

“Operators have told us a lack of visibility of subsea infrastructure and tooling data is holding up their efforts to decommission wells in a timely and cost-efficient manner – an unacceptable situation,” said Pauline Innes, NSTA Director of Supply Chain and Decommissioning.

“TWIST, which we believe is a world first, has got the potential to transform well decommissioning and we are excited to see industry put it to good use and support its expansion,” Innes added.

The 2024 Decommissioning Report of Offshore Energies UK (OEUK) showed that spending on decommissioning activities has risen slightly in 2023 but activities across the decommissioning work breakdown structure (WBS) have tumbled.

In short, the UK has spent more money doing less work in 2023, due to macroeconomic factors including cost inflation, political risk, and competition for resources, Mark Wilson, OEUK’s HSE & Operations Director, said in the report.

“The right support from government is needed if the UK is to become an exemplar of decommissioning and for its sector of the North Sea to thrive,” Wilson wrote in the foreword to the report.

Meanwhile, North Sea operators and the supply chain have been using innovative technologies designed to boost production, help decommissioning, and cut emissions, the North Sea Transition Authority (NSTA) said in its Technology Insights Report in December.

Operators expected to buy £232 million worth of technology from suppliers and spend £78 million on their own research and development in 2024. The figures were £181 million and £66 million, respectively, in 2023.

In recent years, the use of digital technologies and those with net zero applications has expanded rapidly in the North Sea, making up 46 percent of all utilisations in 2023, compared with 37 percent in 2021, according to the report.

“It is encouraging that operators and suppliers continue to invest and work together on the deployment of many hundreds of innovative solutions,” NSTA Technology Manager Ernie Lamza said.

“Collaboration is key to reducing emissions and delivering a speedy and successful energy transition, so I’d urge industry to keep up the good work.”

The North Sea Transition Authority (NSTA) has launched a new database which will provide vital well insights to make subsea well decommissioning more cost-efficient and provide supply chain opportunities.

The Tree and Wellhead Information for Subsea Tooling (TWIST) database provides access to sought-after data on the makeup of well infrastructure, helping companies plan their decommissioning projects better and quickly locate potentially hard-to-find tools.

The new database, which sheds light on subsea well and tree infrastructure, has been developed as a pilot version using data on 423 wells provided by operators bp, CNR International, Harbour Energy, and TAQA, with input from the Well Decommissioning Steering Group (WDSG), part of the Wells Task Force.

“A transparent and pragmatic regulatory regime would oil the machinery and stimulate interest in finding long-term and innovative solutions.”

About 60 percent of the UK North Sea’s topsides and subsea decommissioning will occur between 2026 and 2032, and industry needs to prepare for this now, according to OEUK.

Decommissioning accounted for 12 percent of total oil and gas expenditure in the UKCS in 2023 but this could increase to 33 percent by 2030 – higher than capital investment, the industry body said.

Operators need to plug 200 abandoned North Sea oil and gas wells a year to stay on top of targets but multiple changes to the tax regime are causing continuing economic and fiscal uncertainty and have damaged activity levels, OEUK said.

The NSTA published at the end of November its highest-ever fine of £350,000 on Repsol North Sea Limited (RNS) for behaviour that led to a shut-in at the Flyndre field and hampered economic recovery of petroleum.

In October 2024, the NSTA issued guidance for the conduct of North Sea transactions calling for greater collaborative working between companies to help minimise transaction delays.

Offshore Energies UK has called for a joinedup approach to delivering homegrown energy after the Scottish Government delivered its budget in early December.

“In Scotland, the oil and gas sector support 90,000 jobs and £18.9 billion in GVA. The opportunities as we deliver net zero are even bigger,” Jenny Stanning, director of external relations at OEUK, said

“However, to deliver this in a way that grows Scotland’s economy and provides energy export opportunities, we will need both oil and gas and renewables in an integrated system.”

Added Stanning, “Making the most of this industry’s people, companies, skills and experience is the right path to building the energy industries of the future.”

In company news, the biggest news came from majors Shell and Equinor, which announced that they would merge their UK oil and gas assets, creating a new company which will be the UK North Sea’s biggest independent producer.

Equinor UK Ltd and Shell U.K. Limited will combine their UK offshore oil and gas assets and expertise in a 50/50 incorporated joint venture (IJV), which will be set up to sustain domestic oil and gas production and security of energy supply in the UK, the companies said.

Completion of the transaction remains subject to approvals and is expected by the end of 2025.

“With the once prolific basin now maturing and production naturally declining, the combination of portfolios and expertise will allow continued economic recovery of this vital UK resource,” Shell and Equinor said.

“The new company will be more agile, focused, costcompetitive, and strategically well positioned to maximise the value of its combined portfolios on the UK Continental Shelf.”

While merging the assets, Equinor will retain ownership of its cross-border assets, Utgard, Barnacle, and Statfjord, and offshore wind portfolio including Sheringham Shoal, Dudgeon, Hywind Scotland, and Dogger Bank. It will also retain the hydrogen, carbon capture and storage, power generation, battery storage and gas storage assets.

Shell UK will retain ownership of its interests in the Fife NGL plant, St Fergus Gas Terminal, and floating wind projects under development - MarramWind and CampionWind. Shell UK will also remain Technical Developer of Acorn, Scotland’s largest carbon capture and storage project.

Serica Energy has suspended production from the Triton FPSO again, after a limited resumption of production at the end of November. In early December, however, an issue with one of the compressor seals has been discovered which has resulted in production being suspended once again.

With production at Triton suspended, current Serica production from the Bruce Hub and other assets totals around 28,000 boepd.

Serica Energy said in its trading and operations update at end-November that the UK’s Autumn Budget “has provided much needed clarity over future investment allowances.”

Accordingly, Serica will receive full tax relief against the Energy Profits Levy (EPL) on the costs of the remainder of the Triton drilling programme.

“The increase in the rate of EPL and extension until March 2030, combined with uncertainty about the longer term fiscal regime, however, has increased the economic threshold for longer cycle investments,” Serica said.

Wood has signed three major agreements with bp to provide engineering and project delivery services for their capital projects worldwide. The contracts cover a new master services agreement (MSA)

UK ENERGY

for Engineering, Procurement and Construction management (EPCm) services as well as two extensions to existing long-term frameworks for the provision of Conceptual Engineering and Pre-FEED/ FEED engineering. The new EPCm agreement will run for an initial term of three years with the potential for extensions of an additional four years. Meanwhile the Conceptual Engineering and PreFEED/FEED frameworks have been extended for an additional three years each.

Well-Safe Solutions has been awarded two new contracts totalling $25 million for approximately 170 days of firm work, using the Well-Safe Protector jack-up and Well-Safe Defender semi-submersible.

The scopes comprise of well decommissioning activity in the UK Continental Shelf for Spirit Energy and an additional global operator. Both contracts include options for a further combined duration of up to 140 days in 2025 and 2026 – worth up to $25 million in addition to the firm $25 million backlog.

Independent energy service company THREE60 Energy has been awarded a multi-million-pound contract by a Major North Sea Operator to provide duty holder services to deliver and support endto-end decommissioning for multiple assets in the North Sea. THREE60’s scope of work will commence immediately and will span a period of six years, and all elements of the project will be delivered by the Aberdeen-based team.

Due to the impact of the Ninian outage, EnQuest now expects its full year production to be slightly below its 41,000 to 45,000 boepd guidance range, the company said in an operations update.

Energy solutions business OEG has moved into a new global HQ at The Stratus Building, ABZ Business Park in Dyce, Aberdeen, following a sevenfigure sum investment in a multi-year lease.

The move underscores OEG’s deep commitment to its local roots while serving as a launchpad for its ambitious global expansion in renewables and other key offshore energy markets, the company said.

Orcadian Energy has acquired all of the ordinary shares of HALO Offshore UK Limited from the joint liquidators of Hague and London Oil plc (in liquidation).

HALO has held a number of licences across the Southern North Sea, including participation in wells on Pegasus and Andromeda. Most recently, HALO held a licence over the depleted Schooner field. HALO does not currently hold any licences, Orcadian Energy said in a statement. 

Europe Energy Review

By Tsvetana Paraskova

In 2023 the government said it planned to take full ownership of the gas export network, which it considers an asset of national interest and importance.

“Now that Smørbukk North is in production, Åsgard's future looks even brighter, characterized by high activity and viable development,” Equinor said.

New discoveries and project start-ups offshore Norway, Britain’s offshore wind supply chain opportunities, and milestones in major renewable energy developments across Europe featured in the European energy market at the end of 2024.

Oil & Gas

The Norwegian government has agreed to buy from private companies the majority of the country’s natural gas export network, the Energy Ministry said in November.

The government has now reached agreements with Equinor, Shell, CapeOmega, Hav Energy, Silex Gas Norway, Orlen, and ConocoPhillips to buy their stakes in the Gassled, Nyhamna, and Polarled joint ventures. Not all owners in the system agreed to sell—North Sea Gas Infrastructure AS and M Vest Energy AS did not accept the state’s offer for their interests in Nyhamna and Polarled, respectively.

“The objective is still a full State ownership of Nyhamna JV and Polarled JV,” Norway said.

“The State aims to take over the remaining interests in these two joint ventures when the license periods expires or through an agreement prior to this.”

Equinor has signed an agreement to buy Sval Energi’s 11.8-percent share in the Halten East Unit, an ongoing offshore development in the Kristin-Åsgård area in the Norwegian Sea, which raises Equinor’s ownership to 69.5 percent.

The recoverable reserves in Halten East are estimated to be around 100 million barrels of oil equivalents, of which around 60 percent is gas that will be exported to Europe via Kårstø.

Equinor has also launched oil and gas production at Smørbukk North, a satellite to the Åsgard field in the Norwegian Sea, utilising existing Åsgard infrastructure. Thus, Smørbukk North has low development costs and profitable production with low CO2 emissions and also extends the lifespan of Åsgard.

Equinor has also announced a new oil and gas discovery near the Fram field in the North Sea. The discovery is estimated at between 13 and 28 million barrels of oil equivalent.

Another operator offshore Norway, DNO, confirmed in December that its FalstaffOthello well has opened up a new play in the southern North Sea. Light oil was discovered in Palaeocene sandstones of good reservoir quality with preliminary estimates of gross recoverable resources in the range of 27-57 million barrels of oil equivalent (MMboe) on a P90-P10 basis, with a mean of 41 MMboe.

Together with its partners, DNO is already considering tying back the discovery to existing infrastructure, with the ConocoPhillips Ekofisk hub some 40 kilometres to the west and the Valhall hub operated by Aker BP some 55 kilometres to the southwest.

Equinor has awarded a two-year firm contract to Northern Ocean Wind AS to employ the mobile rig Deepsea Bollsta on the Norwegian continental shelf.

“We have an ambition to maintain our production from the Norwegian continental shelf at a high level towards 2035, supplying the energy that Europe demands,” said Kjetil Hove, executive vice president for Exploration and Production Norway (EPN).

“Our ability to continuously drill new wells is at the heart of this. There is still a large remaining resource potential in our producing fields. We also see attractive exploration opportunities in Norway,” Hove added.

European majors bp, Equinor, Shell, and TotalEnergies have announced a $500 million joint investment commitment, intended to create positive energy access impact for people in key regions over the coming years. The companies’ joint investment is aimed at supporting the UN Sustainable Development Goal 7 (UN SDG7), which aims to ensure access to affordable, reliable, sustainable, and modern energy for all.

Low-Carbon Energy

A new report by UK Steel has highlighted opportunities for the UK steel industry in offshore wind.

UK Steel commissioned an independent report from LumenEE to identify the total steel needed for the rapid expansion of the UK’s offshore wind sector, out to 2050.

Up to 25 million tonnes of steel will be needed in the next 25 years for offshore wind investment around the coast of Britain, according to the report. This single opportunity alone is worth approximately £21 billion in steel purchases.

“The LumenEE findings on offshore wind alone illustrate what’s at stake: £21 billion in steel purchases that could drive a major upturn in UK production. Without decisive action, we risk losing this opportunity and continuing to fund foreign competitors instead of our own economy,” said UK Steel Director-General, Gareth Stace.

Dan McGrail, CEO of RenewableUK, commented, “If the Government and steel industry carefully invests the £2.5bn steel fund in response to this huge growth area, then the wind industry’s Industrial Growth Plan, UK steel production, fabrication and national supply chains can all fall into step as a huge economic boon for the UK.”

In company and project news, RWE, which is developing the Sofia offshore wind farm, noted that the 1.4 gigawatts (GW) project will not only be one of the UK’s largest operational renewable energy assets but will also create £760 million of value for the UK economy, including £181 million for Yorkshire and Humber and £62 million for the North East. That’s according to an RWE-commissioned study conducted by Wavehill Social and Economic Research.

Sofia will be capable of generating power equivalent to the needs of 1.2 million typical households, while fostering community and economic growth across the region and the wider UK, RWE said.

RWE already operates 10 offshore wind farms across the UK. Including the three Norfolk

offshore wind projects from Vattenfall, RWE is developing nine offshore wind projects in the UK, representing a combined potential installed capacity of around 10.5 GW.

Statkraft, Europe’s largest generator of renewable energy, has reached a crucial milestone in the construction of its Thornton Greener Grid Park with the arrival of the first of 620 battery units to be installed on site. The 200-MW two-hour Battery Energy Storage System (BESS) project, located to the east of Thornton, in East Yorkshire, represents an investment of £150 million in the UK’s renewable infrastructure, and is the largest battery scheme in Statkraft’s international portfolio.

Associated British Ports (ABP) has completed its Lowestoft Eastern Energy Facility (LEEF) in a £35 million infrastructure project, supported by the Town’s Fund. Lowestoft – the UK’s most easterly port – will play a key role in the Southern North Sea (SNS) energy sector.

Purpose-built to meet the growing demands of the offshore energy industry, LEEF supports operations and maintenance (O&M) activities and construction phase requirements. The infrastructure strengthens Lowestoft’s position as a key hub for offshore wind and energy markets, while creating significant opportunities for regional growth and sustainability, ABP said.

Enilive, an Eni company focused on mobility services and products, has announced a new agreement with EasyJet to supply a number of flights from Milan Malpensa Airport with Sustainable Aviation Fuel (SAF).

Enilive and easyJet have also signed a Letter of Intent for a potential additional supply of about 30,000 tonnes of pure Enilive SAF at other Italian airports where the airline operates.

CERN (European Organization for Nuclear Research) has signed two corporate power purchase agreements (PPAs) with renewable energy firm Voltalia. Under the terms of the deals, CERN will purchase for 15 years the output of two solar power plants with a combined capacity of 26.8 megawatts, currently under development in the south of France. The combined output of these two plants will be equivalent to the consumption of 19,400 inhabitants.

Ocean Winds marked in mid-November the installation of the final wind turbine at the Moray West offshore wind farm on the way to fully commissioning the project.

The 882-MW wind farm is nearing the end of the construction phase and will become fully operational during 2025 in line with the originally projected commercial operations date. When Moray West comes online, Ocean Winds will be the largest offshore wind operator in Scotland, the company said.

Amazon is investing in three new utility-scale wind farms in Greece, the largest renewable energy deal for Amazon in the country to date. These wind farms will help match Amazon’s electricity use in the region with carbon-free energy, while supporting Greece’s goal of transitioning to more renewable electricity sources, the e-commerce giant said. 

Image: Didier Gauducheau, Voltalia

Image: Amazon

USA Energy Review

By Tsvetana Paraskova

Incoming

President Donald Trump and his energy policies continued to dominate the US oil and gas industry talk at the end of the year.

President-elect Trump has promised a boom in US drilling, with the now famous ‘drill, baby, drill’ catchphrase from the campaign trail. The incoming President has also pledged to undo key climate policies, mandates, and initiatives enacted by outgoing President Joe Biden.

President Trump is expected to prioritise oil and gas from day one. The Trump transition team is reportedly drafting an energy package to expand domestic oil and gas drilling on federal lands and offshore lease sales, and to accelerate LNG export permits.

The oil and gas industry is cautiously optimistic about the new administration and its policies, as it hopes for a permitting reform to speed up energy infrastructure projects, but has warned that ‘drill, baby, drill’ is unlikely to be the narrative in the oil patch in the coming months.

‘Drill, Baby, Drill’?

ExxonMobil does not expect US producers to adopt a “drill, baby, drill” mode once Trump becomes US President, as companies will seek to maintain their spending discipline of the past few years, ExxonMobil Upstream President Liam Mallon said at the Energy Intelligence Forum conference in London in November.

“A radical change (in production) is unlikely because the vast majority, if not everybody, is focused on the economics of what they're doing,” Mallon said at the event, as carried by Reuters.

The priorities of the US oil industry have drastically changed since Trump’s first term in office, as companies are now focused on distributing more of the profits to shareholders. The oil and gas sector has made huge progress in capital discipline and efficiency gains in recent years. Analysts say that prioritising returns to investors and financial frames capable of withstanding oil price volatility will remain paramount for the US shale patch.

Producers continue to favour profit over production growth, so the next US president is unlikely to have a direct impact on America’s shale output, Rystad Energy analysts said ahead of the US presidential election.

“Shale production has proven to be incredibly resilient, and we expect it to continue to play a major role in the global energy landscape for years to come,” said Matthew Bernstein, Senior Analyst, Upstream Research at Rystad Energy.

“At the end of the day, the industry is driven by market fundamentals, not by politics.”

Trump’s

Goals and Impact on Industry

After the election, Rystad Energy said that overall US drilling and completion activity is set to decline by roughly 1 percent in 2025.

“Barring any immediate short-term change to a call on US oil production, it is difficult to formulate a thesis that would reverse the oilfield service trend in 2025 due to the incoming Trump administration,” the analysts wrote in a note.

Moreover, tariffs on products such as Oil Country Tubular Goods (OCTG) and carbon steel plate material, widely used for pressure vessels in oil and gas facilities, could immediately impact operators’ costs, according to Rystad Energy.

“Should Trump implement these measures after re-taking the White House, costs to operators would likely increase in these categories, which could impact activity further against a softer oil commodity backdrop,” Rystad Energy said..

The President-elect’s first energy policy picks signal the new administration’s goal—to boost investments and production of all forms of domestic energy, including fossil fuels, says Ed Crooks, Senior Vice President, Americas, at Wood Mackenzie.

President-elect Trump has picked Chris Wright, the chief executive of oilfield services company Liberty Energy, to be his energy secretary, and Doug Burgum, the governor of North Dakota, to be the interior secretary and head of a new National Energy Council at the White House.

In a separate analysis, WoodMac said that Republican control in the US will move energy policy away from net zero targets, but President-elect Trump’s full agenda will face political and market opposition.

The US under Trump will likely ease the standards on emissions regulations, implement more protectionist trade policies, and remove the US from the Paris Agreement, again, according to Wood Mackenzie.

However, the energy transition is unlikely to be derailed, due to the bi-partisan support for the Inflation Reduction Act (IRA) in Congress, competitive economics for renewable power, and net zero goals from the private sector.

“The IRA has supported over US$220 billion in manufacturing investment and much of this has been concentrated in Republican-led states,” said David Brown, Director, Energy Transition Service at Wood Mackenzie.

“The likelihood of a full IRA repeal is low. However, there could be some amendments to the legislation. Renewables investment could slow, but capacity is set to grow by 243 gigawatts (GW) from 2024-2030 even in our delayed transition scenario,” Brown said.

Growth in US domestic natural gas demand will be supported by deregulation and the need for new power generation in view of the data centre and AI boom, according to WoodMac.

API Calls on New Administration to Bolster US Energy Leadership

Following the presidential election, the American Petroleum Institute (API) released a new policy roadmap for the incoming Trump administration and next Congress to secure American energy leadership and help reduce inflation.

Beginning with an open letter to Presidentelect Trump, the 5-point policy roadmap details concrete steps Washington can take in 2025 and beyond to protect consumers, bolster geopolitical strength, leverage the national resources, reform the US permitting system, and advance sensible tax policy.

API is calling on President-elect Trump to repeal the Environmental Protection Agency’s (EPA) tailpipe rules and the National Highway Traffic Safety Administration’s Corporate

Average Fuel Economy (CAFE) standards to protect consumer choice.

To bolster America’s geopolitical strength, the Trump Administration should lift the LNG permitting pause, swiftly process all pending export applications at the Department of Energy (DOE), and ensure the open access of American energy to global markets, according to API.

To leverage US natural resources, the new administration is urged to issue a new Bureau of Ocean Energy Management (BOEM) fiveyear offshore leasing programme, repeal restrictive onshore leasing rules, starting with the Bureau of Land Management (BLM) Conservation and Landscape Health Rule, and end EPA’s methane fee that misinterprets Congressional intent and does little beyond increasing the cost of production for American oil and natural gas.

API is calling on the Trump team to reform the permitting system by reforming the National Environmental Protection Act (NEPA) and the Clean Water Act, advancing judicial reform, and repealing the Biden-era NEPA rules.

Finally, in terms of sensible tax policy, API urges the new administration to retain the 21% corporate tax rate to ensure global competitiveness, maintain and extend tax provisions for domestic infrastructure investment, and preserve crucial international tax provisions.

“Our country has a generational opportunity to fully leverage U.S. energy leadership to improve the lives of all Americans and bring stability to a volatile world,” API President and CEO Mike Sommers wrote in the letter to President-elect Trump.

“The U.S. energy renaissance has already delivered enormous benefits— America is the world’s largest producer of oil and natural gas, and our energy industry is the envy of the world. But we can—and must—do more.” 

Chris Wright - hief executive of oilfield services company Liberty

Middle East Energy Review

By Tsvetana Paraskova

The OPEC+ group postponed, once again, the start of the unwinding of the oil production cuts, as the biggest national oil companies in the Middle East announced major contracts and corporate reshuffles and milestones.

OPEC+ Delays Supply Additions, Extends Cuts into 2026

OPEC+ ministers decided in early December to delay, again, the planned gradual return of more oil production to the market, in a move that was widely expected by the market and analysts.

OPEC+ producers Saudi Arabia, Russia, Iraq, the United Arab Emirates, Kuwait (UAE), Kazakhstan, Algeria, and Oman, which have been withholding 2.2 million barrels per day (bpd) of crude oil production since last year, decided to postpone the easing of these cuts until April 2025.

The producers had already delayed twice the start of the unwinding of the cuts, with the previous start date to begin increasing production as of January 2025.

Now the output hike has been pushed back by another three months, while the whole period for unwinding the production reductions has been extended to September 2026, from the end of 2025.

“The 2.2 million barrels per day adjustments will be gradually phased out on a monthly basis until the end of September 2026 to support market stability,” OPEC said at the end of the video conference meeting on 5 December.

The UAE, which won at the June 2024 meeting an OPEC+ approval to raise its production by 300,000 bpd in 2025, due to its growing capacity, has agreed to gradually phase in the new output beginning in April 2025 until September 2026.

Many analysts interpreted the delay of the start of production increases to April 2025 as a cautious OPEC+ approach to see where global oil demand is going early next year and how President Donald Trump would approach Iran and Venezuela when he returns to the White House in January 2025.

Overall, the oil market was not impressed by the latest OPEC+ decisions. While the delay to the production hike was mostly baked in in the prices, the slower pace of unwinding the cuts removes some excess supply for 2025 that would have otherwise come if the previous timetable was kept.

“The action taken by OPEC+ eats quite heavily into the surplus that was expected over 2025. However, the extension and the slower return of barrels is not enough to push the market into deficit next year,” said Warren Patterson, Head of Commodities strategy at ING.

The move from OPEC+ would still leave the oil market in a surplus during the first half of 2025, although admittedly the surplus would be more manageable at around 500,000 bpd, compared to 1 million bpd ING had expected previously.

The market is expected to be essentially in balance during the peak demand period

during the third quarter of 2025, but it would return to a surplus of 1 million bpd in the final quarter of 2025, according to ING.

“While the action taken by OPEC+ may potentially provide a higher floor to the market than previously expected, ultimately the group will still have to accept lower prices,” Patterson said.

“OPEC+ faces the ongoing issue of growing non-OPEC supply and disappointing demand growth, largely due to China.”

Major Deals of Middle East’s NOCs

Many of the Middle East’s top national companies announced major agreements and new initiatives.

ADNOC’s new low-carbon energy and chemicals venture grabbed headlines.

Abu Dhabi’s oil and gas giant announced that it was launching a new company, XRG, which will be an international lower-carbon energy and chemicals investment powerhouse with an enterprise value of over $80 billion.

XRG aims to more than double its asset value over the next decade by capitalising on demand for low-carbon energy and chemicals driven by three megatrends: the transformation of energy, exponential growth of AI, and the rise of emerging economies.

XRG will formally commence activities in the first quarter of 2025.

“Building on our unrivalled track record in energy and investments, network of global partners, and strategic market access, XRG will drive sustainable economic growth, foster technological innovation, and deliver the energy and products needed to improve lives around the world,” said Sultan Ahmed Al Jaber, ADNOC Managing Director and Group CEO.

“We are committed to delivering long-term value for our stakeholders and reinforcing Abu Dhabi and the UAE’s role as a global energy and chemicals leader.’’

UAE President, Sheikh Mohamed bin Zayed Al Nahyan, chaired the annual meeting of ADNOC’s board of directors at the end of November, during which the board endorsed

ADNOC’s target to drive AED200 billion ($54.5 billion) into the UAE economy over the next five years through its In-Country Value (ICV) programme, building on AED55 billion ($15 billion) delivered in 2024.

ADNOC has signed local manufacturing agreements with UAE and international companies worth AED72 billion ($19.6 billion) since 2022, as the company looks enable local manufacturing of critical industrial products in its supply chain.

In Saudi Arabia, Aramco and China’s Rongsheng Petrochemical have signed a framework agreement to advance an expansion project at the Saudi Aramco Jubail Refinery Company (SASREF) in Jubail in the Kingdom.

The agreement outlines the cooperation mechanism and planning relating to the design and development of the project, which aims to expand SASREF’s refining and petrochemical capabilities while fostering international collaboration.

The agreement “highlights the potential of the Kingdom’s downstream sector to attract overseas players,” Mohammed Al Qahtani, Aramco Downstream President, said.

The Agreement “highlights

the potential of the Kingdom’s downstream sector to attract overseas players”

Mohammed Al Qahtani, Aramco Downstream President

In another deal, Aramco, TotalEnergies, and Saudi Investment Recycling Company (SIRC) signed a Joint Development and Cost Sharing Agreement (JDCSA) to assess the potential development of a sustainable aviation fuels (SAF) plant in Saudi Arabia.

The assessment will focus on harnessing innovative engineering and technology solutions that seek to recycle and process local waste or residues from the circular economy (used cooking oils and animal fats) to produce SAF.

Wellpro Group & Omega Well Intervention provide a complete Thru Tubing, Inflatable Packer & Well Intervention portfolio including operational design, project management, service, rental & sales.

The Saudi oil giant also announced the signing of a shareholders’ agreement with SLB and Linde to build what the companies said would be one of the largest carbon capture and storage (CCS) hubs in the world. Under the terms of the shareholders’ agreement Aramco will take a 60-percent equity interest in the CCS hub, with Linde and SLB each owning a 20-percent stake.

Phase one of the new CCS hub in Jubail, in Saudi Arabia’s Eastern Province, is expected to capture and store up to nine million metric tonnes of CO2 annually, and construction is expected to be completed by the end of 2027. Later phases are expected to further expand its capacity, Aramco said.

In Qatar, state firm QatarEnergy and Shell have entered into a new long-term sale and purchase agreement to supply three million tonnes per annum (MTPA) of liquefied natural gas to China.

LNG deliveries under the SPA will begin in January 2025, as the agreement highlights the continued growth of China’s LNG market,

which is projected to be the largest globally, QatarEnergy said.

The Qatari state company has also expanded its oil and gas exploration interest outside the tiny Gulf nation.

QatarEnergy has entered into an agreement with Chevron to acquire a 23-percent working interest in the concession agreement for the North El-Dabaa (H4) Block, in the Mediterranean Sea offshore Egypt. The block’s operator, Chevron, will retain a 40-percent interest, while the other partners are Woodside with 27 percent and Tharwa Petroleum Company, an Egyptian state company, with 10 percent.

The agreement further strengthens QatarEnergy’s partnership with long-time partner Chevron, said Saad Sherida Al-Kaabi, Qatar’s Minister of State for Energy Affairs and president and CEO of QatarEnergy.

QatarEnergy has also entered into an agreement with TotalEnergies to buy an additional 5.25-percent interest in block 2913B (PEL 56) and an additional 4.695- percent interest in block 2912 (PEL 91), both located in the Orange Basin, offshore Namibia.

“This agreement marks another important step in working collaboratively with our partners towards the development of the Venus discovery located on block 2913B,” Al-Kaabi noted. 

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

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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

OVER THE YEARS

1 YEAR AGO

1 Year Ago - $79.89

Oil prices rose sharply after Iran rejected calls to end support for attacks by Houthi rebels on vessels in the Red Sea and sent a warship to the key trading route. Oil prices were also supported by hopes of strong demand over China’s spring festival holidays in February and economic stimulus in the country.

5 YEARS AGO

5 Years Ago - $64.45

Oil futures fell for a fifth session in a row, with the U.S. benchmark logging its lowest finish in almost six weeks as the immediate risk of a bigger U.S.- Iran conflict continued to fade, easing worries about potential global supply disruptions. President Donald Trump backed away from military confrontation, as increased tensions in the Middle East and higher Oil prices loomed impacted consumers.

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10 YEARS AGO

10 Years Ago - $45.13

The price of Brent crude dropped below $50 a barrel for the first time in six years. Slowing global growth and increased supply of oil and gas had pushed prices sharply lower in recent weeks. Many observers expected the price of oil to fall further as North American shale producers continued to supply increasing quantities of oil and gas, and the oil-producing group Opec resisted calls for cuts in production to support prices.

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It is renowned for excellence in the provision of services that unlock opportunities for its members, helping the supply chain to win business across the globe.

The EIC provides one of the most comprehensive sources of energy projects and business intelligence in the energy sector today.

UBADARI GAS FIELD

BP has reached a final investment decision to develop the field along with the Tangguh Ubadari CCUS and Compression Project. Saipem together with PT Meindo Elang Indah has been awarded an EPCI contract. Saipem's scope of work includes the EPCI of two production platforms, one wellhead platform for CO2 reinjection and approximately 90 km of associated pipelines.

BASS STRAIT DECOMMISSIONING PROGRAMME

The Environment Plan to plug and abandon 26 wells consisting of 21 platform wells and five subsea wells has been approved by NOPSEMA. Work to plug and abandon the 26 wells commenced on 28 October and is being delivered by KeppelFel's MOD V Class B rig, Valaris 107.

MOPANE-1X OIL DISCOVERY

Galp Energia has discovered light oil and gas condensate in its project's second appraisal well. Partners will now analyse data, moving toward future activities, including more exploration and appraisal wells and 3D Seismic studies, which will start in December.

HARRIET ALPHA PLATFORM DECOMMISSIONING

McDermott has been awarded a major contract from Santos to decommission the Harriet Alpha platform and related infrastructure in Western Australia. This contract covers engineering, procurement, removal, and disposal operations.

ATLANTA HEAVY OIL FIELD (PHASE 1 – ATLANTA FPSO)

Brava Energia announced it has signed three contracts to undertake the drilling and tieback of two wells in Atlanta and two wells in Papa-Terra, with the potential for drilling a well in Malombe. The contracts total US$200m. Brava has also ordered two subsea Christmas trees from OneSubsea for the Atlanta field. Lastly, the company has signed a contract with Baker Hughes for the acquisition of lines and risers for the Atlanta wells, with an option for Malombe.

AFINA OIL AND GAS DISCOVERY

Springfield has announced that appraisal well-test activity has been successfully completed on the discovery. A drill stem test (DST) on the Cenomanian play flowed at a maximum rate of 4500 b/d of oil. Additionally, a mini-DST conducted on the Turonian sandstone confirmed the presence of gas/ condensate and indicated an estimated flow rate potential of up to 12,000 boe/d

LAC DA VANG OIL FIELD

Yinson reported that PTSC Asia Pacific, a JV between Yinson and PTSC, has been awarded a contract for the provision, charter, operation and maintenance of an FSO for the project. The FSO will be chartered for a period of 10 years with an option to extend up to 5 years that bring the total contract value to $416 million. The newbuild FSO will have a storage capacity of 500,000 bbls. Construction is expected to take about 2 years with operations anticipated to begin in Q4 2026.

BLOCK 29 – POLOK AND CHINWOL OIL DISCOVERIES

McDermott has been awarded a contract to supply the operator with comprehensive FEED services for the project's engineering, procurement, construction, and installation (EPCI) of subsea, umbilicals, risers, and flowlines (SURF) equipment. The engineering delivery will be led from McDermott's Houston office.

CHOLA-1 GAS AND CONDENSATE DISCOVERY

The Chola-1 well, drilled in a water depth of approximately 1,700m has flowed gas and condensate on test across four different objects. Object 1 had a flow rate of 10.44 MMcf/d of gas and 111 boe/d of condensate. This hydrocarbon success in Object 1 was classified as a New Pool discovery. Additionally, Object 2 had a flow rate of 18.27 MMcf/d of gas and 368 boe/d of condensate, and Object 3 had a flow rate of 3.06 MMcf/d of gas.

BLOCK 58 FIELD DEVELOPMENT (GRANMORGU FPSO

TotalEnergies has formally awarded the project's EPC contract to SBM Offshore. The deal features an all-electric drive FPSO, aimed at reducing emissions by eliminating routine flaring. The vessel is expected to have an expected production capacity of up to 220,000 barrels of oil per day and associated gas treatment capacity of up to 500 million cubic feet per day. SBM will manage O&M for the FPSO.

OTHELLO OIL DISCOVERY

DNO Norge has discovered oil in Palaeocene sandstones of good reservoir quality with preliminary estimates of gross recoverable resources between 27 to 57MMboe in the southern North Sea off Norway. Falstaff, the primary target, was dry. The Othello target, however, hit a 16-metre net oil-bearing reservoir. The discovery well and sidetrack were drilled using Noble Corp's Noble Invincible jack-up rig. Potential development options include tie-backs to either the ConocoPhillips Ekofisk hub located 40km west or Aker BP's Valhall hub 55km southwest.

ADNOC WELL DIGITALISATION PROGRAMME

Jereh Group has signed a $920 million EPC contract with ADNOC Onshore to implement an AI-driven well digitalisation program across ADNOC's onshore Bab, Bu Hasa, and Southeast fields in Abu Dhabi. The project will digitise over 2,000 wells, integrating advanced remote sensing and operational technologies to enable real-time data transmission, monitoring, and analysis.

Well Management and Intervention Could Boost Energy Supply

By Tsvetana Paraskova

Well management and well intervention services, as well as the entire service supply chain of the oil and gas industry, are set to benefit from an uptick in upstream investments as legacy producing countries aim to replace maturing supplies while oil majors explore for oil and gas opportunities in new areas such as Guyana, Namibia, and Cote d’Ivoire.

Even as the world now invests almost twice as much in clean energy as it does in fossil fuels, upstream investment is now estimated to have rebounded to 2017 levels, according to the International Energy Agency (IEA).

Upstream Investment Rising

Upstream oil and gas investment increased globally by 9 percent in 2023 and looks set for a 7 percent rise in 2024, with most increases coming from the national oil companies (NOCs) in the Middle East and Asia, the IEA said in its World Energy Investment 2024 report.

Upstream oil and gas investment is expected to have reached $570 billion in 2024, following a 9-percent rise in 2023. This is being led by Middle East and Asian NOCs, which have increased their investments in oil and gas by more than 50 percent since 2017, and which account for almost the entire rise in spending for the 2023-2024 period, the IEA said.

There is also a significant wave of new investment is expected in LNG in the coming years as new liquefaction plants are built, primarily in the United States and Qatar.

Rising demand for oil and gas means that global upstream oil and gas investment needs to increase by 22 percent annually by the end of this decade, to ensure adequate supplies due to growing demand and cost inflation, a report by the International Energy Forum (IEF) and S&P Global Commodity Insights showed in June 2024.

The report found that annual upstream investment will need to increase by $135 billion to a total of $738 billion by 2030 to ensure adequate supplies, up by 15 percent compared to the assessment a year ago,

due primarily to rising costs and a stronger demand outlook.

In 2024, upstream investment is expected to have more than doubled from 2020’s low of $300 billion and be well above 2015-2019 levels of about $425 billion, the IEF and S&P Global Commodity Insights said.

“A cumulative $4.3 trillion will be needed between 2025 and 2030, even as demand growth slows toward a plateau,” the authors of the report wrote.

Joseph McMonigle, Secretary General of the IEF, commented, “Well-supplied and stable energy markets are critical to making progress on climate, because the alternative is high prices and volatility, which undermines public support for the transition as we have seen in the past two years.”

Exploration Revived

High-impact oil and gas exploration is also critical for companies to rejuvenate their resource portfolio, analysts at Wood Mackenzie say.

“What can be said is that successful exploration cuts carbon intensity, lowers the cost of oil and gas to consumers, and adds value for both resource holders and explorers,”

Andrew Latham, Senior Vice President, Energy Research, at WoodMac said in a report why high-impact exploration is still needed.

“As demand is proving resilient, investment in new supply is needed to displace dirtier alternatives.”

According to WoodMac’s report, deepwater will offer most new opportunities for

exploration as most of the world’s deepwater basins, in waters from 400 metres to over 3,000 metres, are barely drilled.

International oil and gas majors have recently boosted their efforts at deepwater exploration, looking to unlock the next frontier, Latham says.

The NOCs are also keen to explore deepwater areas.

“Increasingly, national oil companies are following suit, as government mandates to increase production and ensure domestic energy security prevail,” Latham notes.

Oilfield Services Firms Optimistic about Long-Term Industry Growth

All these encouraging signs in upstream spending and offshore exploration would benefit the oilfield services supply chain and companies working in well management and well intervention.

SLB, the world’s largest oilfield services provider, said on its Q3 earnings call that despite weaker demand in China and softer economic growth rates in some developed economies in 2024, the company continues to believe in the upcycle of the oil and gas industry.

“Despite these evolving market conditions, we believe the long-term fundamentals for oil and gas remain in place,” SLB chief executive officer Olivier Le Peuch said.

“Demand for energy is increasing and energy security remains a global priority, as witnessed by recent commodity prices fluctuations tied to geopolitical tensions in the Middle East,” the executive added.

“Internationally, gas investment remains strong, particularly in Asia, the Middle East, and the North Sea, and is expected to grow regardless of OPEC+ decisions on oil production,” Le Peuch noted.

Short-cycle oil investments have been more challenged, but longcycle deepwater projects globally and most capacity expansion projects in the Middle East remain economically and strategically favourable, according to SLB.

The company expects “a sustained level of global upstream investment in the years to come, with the secular trends of digital and industry decarbonization extending the investment horizon,” Le Peuch said.

Well Intervention in UK North Sea Could be Massive Opportunity

In the UK North Sea, well intervention is a huge opportunity to access resources in a more timely, clean, and cost-effective way and support the UK’s supply chain, the North Sea Transition Authority (NSTA) said in its annual 2024 Wells Insight Report.

Currently, well intervention is able to provide hydrocarbon production at a cost of less than £12 per barrel of oil equivalent (boe), which is a very attractive option at today’s oil and gas prices, the NSTA said in its report.

Moreover, well intervention requires fewer operational days, less construction material, minimal waste disposal, and lower fuel burn than drilling a new well, and therefore produces lower emissions.

UK North Sea operators should strive to boost their well intervention activity to extend the production lifespan of their wells, and to provide a stable flow of work for the UK’s world-class supply chain, the authority said.

Well intervention activity outside of restoring shut-in wells remained low with just 85 optimization jobs completed in 2023 and a decline in safeguarding jobs from 208 in 2022 to 152 in 2023, the NSTA’s report found.

The authority has already held one-to-one sessions with leading North Sea operators to encourage more well interventions. It has also completed a detailed study of the 795 shut-in wells to understand what percentage could be brought back into production, the NSTA said.

“Well intervention work can and does produce impressive results, boosting efficiency and providing cleaner and cost-effective production,” said Carlo Procaccini, NSTA Chief Technical Officer.

“We expect that bringing together operators with the supply chain will highlight significant opportunities for everyone.” 

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Destec Engineering Ltd.: Pioneering High-Pressure Containment and On-Site Machining Solutions

Delivering 55 years of innovation and precision, Destec Engineering provides industry-leading portable machine tools and on-site services, reducing costs and enhancing efficiency for the oil, gas, petrochemical, and power generation sectors.

For 55 years, Destec Engineering Ltd. has delivered high quality and innovative engineering solutions to industry challenges. Specialising in ‘High Pressure Containment’ and ‘On-Site Machining’, the company has developed both products and services for the oil and gas and power industry. Formed in 1969, Destec now takes pride in its most versatile and a very wide range of in-house designed and manufactured portable machine tools.

With their distributors spread across the world in six continents, Destec has become indispensable to the oil and gas industry. The company is committed to the design and manufacture of portable machine tools, where accuracy is of paramount importance. Destec has a fully equipped machine workshop with a wide selection of CNC lathes, vertical boring and milling machines. Powered by an experienced design staff who are actively engaged in the design and development of their products, Destec provides supporting calculations and stress analysis for their products and use in-house developed computer programmes. Serving clientele all across the oil, chemical and petrochemical related industries, power generation, steel, marine and others, Destec’s well-equipped team backed by the most modern design and manufacturing equipment works closely with the clients to reduce costs. Destec Engineering has designed, developed and built special purpose machines for the oil, petrochemical and nuclear industries. Their multi-disciplined trained technicians combined with the years of expertise provide the best

on-site services which not only significantly reduces the personnel on the field but also is less harsh on the client’s pockets.

Known for their quality assurance, their clients are drawn to the versatility and adaptability of their products coupled with accuracy. Destec serves the client’s needs best through their cost-efficient solutions and their perfect surface finished products ensure that they hold well in-situ. Over the years, they have generated a sense of trust in their clients with their qualityassured products and onsite services.

Destec stands tall as a one-stop solution for all the machinery requirements. This implies cutting down significantly on the costs of stripping down, transporting to a machine shop, returning to site, and reassembly. That is why their clients rely on trustworthy services of taking a special-purpose machine to the job instead.

Destec’s products are the most-trusted by the oil and gas industry with their years of experience on the use of high-pressure and high-temperature metal-to-metal static sealing. Their engineers are driven by quality assurance and follow established codes and standards for design modifications. Destec’s on-site machining service uses portable machines to carry out those modifications and re-build on site.

With their years of experience on the field and a passion-driven team of engineers, Destec has created a niche for its products and services which are unparalleled in the industry. 

COMMISSIONING

• Cable Jet Trenching, Inter-Array & Export, Fibre Optic, Interconnector

• Cable Remedial Lowering

• Energised Cable Lowering

• Pipeline Trenching, Umbilical, Flexi, Trunklines

IRM

• Cable Deburial

• Cable Cutting and Removal

• Cable Freespan Correction

• Pipeline Deburial / Access

• Pipeline Freespan Correction

• Rock Dump Dispersal

• Pre Cut Trench Debris Clearance

• UXO & Salvage Deburial / Access

• Harbour Clearance / Deepening

• Spud Can Clearance / Cleaning

• Monopile Footprint Seabed Levelling

• Subsea Structure Deburial / Access

• Jack Up Footprint Seabed Levelling

PRE - COMMISSIONING

• Sandwave Clearance

• Route / Debris Clearance

• Boulder / Rock Clearance

• Seabed Levelling / Deepening

DECOMMISSIONING

• Subsea Structure Deburial / Access

• Pipeline Lowering

• Mattress Lowering / Removal

• Cable & Pipeline Cutting / Recovery

The Growing Role of Lokring in Reducing Costs and Enhancing Safety in Piping Installations

Lokring has always had an application in cases where hot work poses a high risk — i.e. where the atmospheric conditions make welding a massive safety consideration. However, as more and more operators become comfortable with use of the product, there becomes more opportunities these customers are willing to use Lokring on.

This began with more applications, such as; open and closed hazardous drains and vents, gaslift, flare gas, propane, butane, LPG, hydrocarbon, sour water and sour gas, diesel and chemical injection. But more and more, we are seeing entire scopes of new pipework installation being carried out using Lokring.

Furthermore, with Lokring, fabrications can be made onsite and systems and can be fully fieldrouted, significantly reducing design, fabrication and off-site costs while still enhancing safety. You don't have to necessarily fabricate onshore and ship pipework offshore. This is all done with an ASME B31 code qualified connector meaning the system is still fully welded.

Several customers have found this to reduce their overall install costs by between 25% and 45%. The saving is dependent on the requirement of each scope.

As well as the ease of installation; there is no post-weld heat treatment (PWHT), no decontamination, no flushing, no purging, no hot-work permits and no enclosures or fire tents, no atmospheric tests and possibly a reduction in scaffolding. The rework rate of Lokring is much lower (0.0015 vs ~10%) whilst eliminating heat affected zone (HAZ) issues. The non-destructive testing (NDT) costs, which is sometimes as much as the weld itself is also eliminated.

Welding is an expensive process. It’s not just about the actual weld. There are numerous challenges associated with the work as a whole. All of this adds up to time, which leads to increased costs. 

Wellvene supports the global energy market by designing, manufacturing and qualifying bespoke, quality-assured equipment for well completion, intervention, integrity & P&A operations.

Engineered Well Solutions

Bespoke solutions for a wide range of well completion, intervention, and integrity operations.

Intervention Services

Redefining deployment methods for platform slickline, e-line, and DSL based well intervention operations.

Flow Control Solutions

Offering a variety of landing nipples, profile plugs, and equalising devices to suit new and existing OEM profiles.

Plug and Abandonment Services

Delivering safe and efficient well P&A tool packages and bespoke solutions for ageing well stock.

Safety Valve Remedial Services

A single-source solution to reinstate DHSV functionality and production within a single well campaign.

DHVI: Camera and Caliper Inspection

Equipping you with a clear and accurate visualisation of your wellbore, we help you identify and solve issues faster.

Intervention Operations Redefined

PATENT PENDING

> Eliminates use of a wireline mast

> Eliminates working under a suspended load

> Reduces red zone working

> Single lift well-to-well transfers

> Increases operational efficiency

> Reduces POB

Chevron, Woodside Announce Major Asset Swap Deal in Western Australia Oil, Gas Operations

Chevron has made a swap deal with Woodside in oil and gas operations in Western Australia.

As per the deal, Chevron would sell its interest in North West Shelf venture and take over all of Woodside’s interest in the $34 billion Wheatstone liquefied natural gas (LNG) project and an affiliate gas project.

The deal would also see Chevron paying up to $400 million to Woodside.

“This transaction simplifies our portfolio, improving our focus and efficiency by consolidating our position in our operated LNG assets,” said Woodside CEO Meg O’Neill.

According to Reuters, Woodside’s shares were down 1.7%, in line with broader losses in the Australian energy sub-index. Thus, Woodside will depart from Wheatstone. It had struck a deal in 2015 to buy into the project.

Currently, Woodside’s stake in North West Shelf would increase to 50%. The asset swap deal comes a few days after Woodside Energy received environmental approval from the Western Australian state to prolong the North West Shelf LNG project until 2070.

Meanwhile, the deal signifies the end to Chevron’s four-decadeold participation in the North West Shelf venture, which is till date Australia’s largest LNG exporter.

Reuters reported that this move comes as Chevron ramps up efforts to consolidate its focus on key Australian assets, including the Gorgon LNG venture.

Notably, the transaction still remains subject to approvals on competition and by the foreign investment board and is not expected to be completed until 2026. 

deepC Store to appraise CO2 permit offshore Australia

Australia’s deepC Store has lined up ABL Group company AGR to design the appraisal well drilling and injectivity testing programme for deepC Store and Azuli’s large-scale carbon dioxide storage site on the G-14-AP permit in the Browse basin offshore Australia.

The G-14-AP permit is one of the two offshore CO2 storage acreages (the other being G-13-AP permit) that were awarded to deepC Store and Azuli in August 2024 by the Australian Commonwealth government.

CCS developer deepC Store is the designated operator of the G-14AP permit and the associated CStore1 project and estimates that this permit area contains carbon storage potential of approximately 1 gigatonne of CO2.

A key activity to technically demonstrate this large-scale CO2 storage potential is to execute an appraisal well drilling and injectivity testing programme, noted deepC Store.

Commenting on the contract award, deepC Store’s managing director, Daein Cha, said: “We are very pleased to work with AGR for progressing one of its key technical activities for G-14-AP. This relationship is an important component of our world class CO2 storage development.” 

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Australia’s $211 billion nuclear plan to change uranium mining

Australia’s opposition leader, Peter Dutton, has unveiled a A$311 billion ($211bn) plan to introduce nuclear power into the country’s energy mix, a proposal that could radically alter the nation’s energy policy and its uranium mining industry.

The scheme, based on an economic modelling by Frontier Economics, proposes the construction of seven nuclear power plants by 2050, with the first expected to start operations by 2036.

If successful, the plan would transform Australia, which is grappling with rising energy demands and the need for more reliable and affordable electricity, into a nuclear-powered nation.

Dutton, leader of the centre-right Liberal Party, has positioned nuclear power as the cornerstone of Australia’s economic future, calling it essential for decarbonizing the grid, lowering energy costs, and ensuring a stable electricity supply.

“Nuclear power will underpin the economic success of our country for the next century,” Dutton said, according to Bloomberg. “This will make electricity reliable. It will make it more consistent. It will make it cheaper for Australians, and it will help us decarbonize.”

Leaders divided

The plan is already sparking fierce debate, as its success would not only transform Australia’s energy landscape but also change its uranium mining industry, which has long been restricted despite the nation’s vast reserves.

Australia is currently the world’s fourth-largest uranium producer and holds an estimated one-third of the planet’s known reserves. Yet, uranium mining remains banned in Western Australia and Queensland, two states with major deposits.

While South Australia is home to three operational uranium mines — including the Olympic Dam, which is the largest known uranium deposit in the world — mining activity remains limited. The other active sites, Four Mile and Ranger, have smaller footprints, with Ranger nearing the end of its lifecycle. This underutilization contrasts sharply with growing global demand for uranium as countries seek cleaner alternatives to fossil fuels.

Critics also argue that while Australia’s parliamentary Coalition, consisting of the Liberal Party and the Nationals, is dedicated to achieving net zero emissions by 2050, Dutton’s preferred approach would likely result in increased emissions leading up to that year.

Climate Change and Energy Minister Chris Bowen warned that the situation would likely jeopardize Australia’s ability to meet the global goal of limiting climate change to two degrees Celsius. He pointed out that the modelling assumes electricity demand will rise less than the government anticipates, despite the expanding use of energy-intensive artificial intelligence and the surging popularity of electric vehicles.

Bowen described the plan as “a dangerous error,” cautioning that it could leave Australians without sufficient energy to meet their needs.

Advocates of Dutton’s nuclear plan believe that lifting mining restrictions is a logical next step to ensure a steady domestic uranium supply. Doing so could unlock billions of dollars in economic opportunities, attract foreign investment, and create thousands of jobs. Western Australia, for instance, could see dormant projects revived. 

Coal demand hits record with Australia bulking up

Australia dominates the list of nations developing or expanding coal mines aimed at export markets, tapping record demand for the carbon-polluting fuel, which is projected to edge higher until at least 2027.

The analysis from the International Energy Agency, released at its Paris headquarters on Wednesday, found the world’s consumption of coal is set to rise 1 per cent this year to 8.77 billion tonnes.

Growth in demand for the fossil fuel in China, India and developing nations in Asia is more than offsetting a further slowdown in Europe and North America, which have largely turned their back on a fuel that is a primary contributor to climate change.

Still, the rapid deployment of clean energy technologies is reshaping electricity generation, where two-thirds of the world’s coal is used, said the IEA’s director of energy markets and security Keisuke Sadamori.

“As a result, our models show global demand for coal plateauing through 2027 even as electricity consumption rises sharply.”

A new peak for coal use comes after the COP29 international climate summit in Baku, Azerbaijan, ended without a pledge to transition away from fossil fuels, and as 2024 looks set to be the hottest year on record, according to the World Meteorological Organisation.

Australia, the biggest metallurgical coal exporter, is expected to become the fourth-largest producer of coal overall by 2027, overtaking the US and Russia.

How do you build a hydrogen economy in the Highlands of Scotland?

TLaura Petrie is a partner at Brodies LLP, specialising in energy.

It is an exciting time to be involved in energy in the Highlands of Scotland.

he Inverness and Cromarty Firth Green Freeport recently set out its plans to develop a state-of-the-art hub in the Cromarty Firth for the production, storage and distribution of green hydrogen throughout Scotland, the UK and out to Europe.

In the next ten years, hydrogen will become a key element in the energy transition matrix, and the readily-available water supplies, coupled with significant excess electricity from offshore wind power sites that are abundant in the region, means this is a prime location to base these types of projects.

So, what steps are needed to build a hydrogen economy in this particular region?

Hydrogen generation development

There are already a number of projects across the Highlands focused on hydrogen generation. As well as the Cromarty Hydrogen Hub, there is a hydrogen hub in development in Oban, in the South-west of Scotland, and several whisky distilleries are investigating independent hydrogen generation and proposals for hydrogen refuelling sites throughout the region.

While it's early days for these projects, there is a need for specific supplies to support this growing industry.

Transporting hydrogen is key

The diverse nature of the Highlands – steep hills, sweeping A-class roads and winding, sometimes single-track roads - means that ensuring appropriate infrastructure is in place for hydrogen transport is key to unlocking the viability of the economy. Whether this would be by road or pipeline is undecided for now, but there are several factors at play for determining the best option.

Currently, there is a shortage of road tankers suitable for the haulage of hydrogen in the UK and internationally. Coupled with a shortage of viable steel for building more tankers, there is a need to adapt or import more tanker capacity. Road hauliers should consider how best to meet that growing need for transport options in the near term.

Moreover, the opportunity to develop a bespoke hydrogen pipeline network, traversing Scotland, the UK and extending over to Europe, remains under consideration.

The Net-Zero Technology Centre in Aberdeen continues to assess the viability of constructing the 'Hydrogen Backbone Link,' which would connect Scotland with Ireland and either the Netherlands and/or Germany. This follows a direct request from the German government to the UK, to consider constructing a North Sea pipeline that would deliver hydrogen into the German market.

Bigger picture

Ongoing construction requirements for each of the development projects, alongside the possibility for pipeline construction, means that there are going to be significant developments required in other areas, to meet the demand for resources.

Movement of skilled workers from other regions (permanently and/or on a transient basis) will increase the need for suitable accommodation, while movement of both hydrogen and people will need improvements to key infrastructure – an area the public sector needs to be encouraged to develop.

There will also be increased demand for raw materials and manufacture of component parts for hydrolysers, control panels, pipework and a range of other production elements. These items will need transported and stored during the construction phase, leading to other opportunities for hauliers and those with yard space.

First steps

For those with the stock, skills and services to support the development of the Highland hydrogen economy over the next ten years, now is the time for them to refresh terms and conditions, overhauling stock and preparing their position for tendering as the projects progress.

In addition, continual lobbying to upgrade infrastructure and have a transport network in place, will support the growing hydrogen industry, and ensure that once produced, the hydrogen has somewhere to go. 

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Advancing Sustainability and Efficiency: R&D Innovations in Well Management

Research

and development in well management

are critical aspects of ensuring the efficiency, safety, and sustainability of oil and gas extraction processes.

This field has seen significant advances over the past few decades, characterised by integrating cutting-edge technology and innovative methodologies.

One of the key areas of focus in well management R&D is the development of advanced monitoring and control systems. These systems utilise real-time data analytics, sensor technologies, and automation to improve the accuracy and responsiveness of well operations. By enabling continuous monitoring and real-time adjustments, such technologies not only enhance production efficiency but also minimise risks associated with environmental hazards and operational failures. One paramount example of advanced monitoring in well management is the use of fibre optic sensing technology. These sensors can be installed along the length of a wellbore to deliver constant data on temperature, pressure, and acoustic signals. The information garnered from these sensors can diagnose potential issues such as leaks, sand production, or unwanted water influx in real-time. Moreover, Artificial Intelligence and Machine Learning algorithms are now increasingly utilised to predict and optimise well performance. By analysing large datasets from various wells, AI-driven models can forecast production trends, identify maintenance needs before failures occur, and propose adjustments to enhance overall efficiency. This predictive capability is a game-changer, significantly reducing operational costs and unplanned downtimes.

Another pivotal aspect of R&D in well management involves improving drilling techniques and materials. Traditional drilling methods can be costly and environmentally intrusive. However, advances in engineering and material sciences have led to the creation of more efficient drilling techniques, such as directional drilling and hydraulic fracturing, which have transformed the landscape of

oil and gas extraction. Directional drilling allows operators to reach deposits that were previously considered inaccessible, thereby maximising resource recovery while minimising surface disturbances. In addition, technologies like Managed Pressure Drilling offer more control over drilling variables, reducing the risks associated with high-pressure zones and improving safety. Simultaneously, advances in drill bit technology, including the use of polycrystalline diamond compact bits, have yielded significant efficiency gains, enabled faster drilling rates and longer bit life, thus lowering overall operational costs. The development of more durable and sustainable materials for drilling equipment has substantially increased its lifespan and performance. Nanotechnology, for instance, has been leveraged to create more resilient and wear-resistant coatings for drilling equipment, extending its life cycle and enhancing its performance under extreme conditions. Researchers are continually exploring composite materials and alloys that not only improve the strength-to-weight ratio of drilling tools but also resist corrosion and other forms of material degradation.

Sustainable practices have also taken centre stage in well management research and development. With growing concerns about climate change and environmental sustainability, the oil and gas industry are under significant pressure to reduce its carbon footprint and ecological impact. This has led to substantial investments in R&D aimed at enhancing well integrity and minimising leaks and spills. Innovations such as improved well cementing techniques, and the use of nontoxic drilling fluids, are just a few examples of how the industry is evolving towards greener practices. Advanced well cementing technologies ensure a more secure sealing of the annular space between the casing and the borehole, preventing fluid migration that can compromise both the integrity of the well

and the surrounding environment. Non-toxic drilling fluids, on the other hand, mitigate the environmental risks associated with traditional chemical-based fluids. In addition, implementing carbon capture and storage (CCS) technologies underscores the industry’s commitment to mitigating its environmental impact. By capturing CO2 emissions at the source and storing them underground, CCS plays a crucial role in the overall strategy to combat climate change while maintaining the viability of well operations. Research in this field is focused on identifying optimal storage sites, improving the efficiency of CO2 capture processes, and developing monitoring techniques to ensure the long-term stability of stored carbon dioxide. This kind of proactive environmental stewardship is essential for the industry’s social license to operate, as well as for meeting increasingly stringent regulatory requirements.

Integrating digital technologies, advanced materials, and sustainable practices through continuous R&D efforts is crucial for the future of well management. These innovations not only enhance operational efficiency and safety but also help to address the broader environmental and social challenges facing the industry. As R&D initiatives evolve, they offer promising solutions that could revolutionise how we manage and utilise well resources, ensuring a more sustainable and resilient energy landscape for future generations. In order to support these initiatives, the UK government has implemented various initiatives to support these advancements, such as funding programs, grants, and collaborations with industry and academic organisations. These initiatives aim to encourage the adoption of emerging technologies and the development of novel solutions.

By exploring funding schemes, such as HMRC’s R&D Tax Relief Scheme, companies engaged in pioneering projects can enjoy the potential benefits of financial incentives for their research and development activities. Leyton, an esteemed leader in innovation funding, offers expert guidance and support to assist firms in securing financial backing for their research and development initiatives. Leveraging their extensive experience, Leyton ensures that companies can confidently apply for R&D funding, maximising the rewards for their innovative activities.

Mariusz Kucharek PhD Senior Technical Consultant - R&D Tax Incentives, Leyton UK

Australian engineering and professional services company Worley will provide reimbursable engineering, procurement and construction (EPC) services to U.S. energy major ExxonMobil for the enabling works, infrastructure and interconnects scope of the latter’s planned low-carbon hydrogen and ammonia facility in Baytown, Texas.

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Worley picks up EPC contract with ExxonMobil

As disclosed, the contract is subject to the final investment decision (FID), as well as supportive government policy and necessary regulatory permits.

Chris Ashton, CEO of Worley, stated: “We are delighted to continue our strategic, global relationship with ExxonMobil in its execution of upcoming projects, particularly in delivering this EPC project on the US Gulf Coast, which contributes significantly to strengthening Worley’s backlog.”

The Baytown facility is expected to produce 28.3 million cubic meters (1 billion cubic feet) of low-carbon hydrogen daily and nearly 1 million metric tonnes (more than 1 million tons) of ammonia annually while capturing more than 98% of the associated CO2 emissions. A final investment decision (FID) is expected in 2025 with an anticipated startup in 2029.

ExxonMobil said the facility will leverage advanced carbon capture and storage (CCS) technologies to reduce emissions associated with hydrogen production, adding that by creating U.S. jobs and supporting community development initiatives, the project’s construction will also bring economic benefits to Baytown, the Houston area and Texas.

It is worth noting that in September 2024, the U.S. major signed an agreement with Abu Dhabi National Oil Company (ADNOC) under which the latter will acquire a 35% equity stake in the facility. Reportedly, the agreement will help reduce greenhouse gas (GHG) emissions across hard-to-decarbonize sectors, including industry, energy and transportation, meet rising demand for lower-carbon fuels and accelerate a net-zero future. 

PD&MS Group wins multi-million-pound EPCm contract with INEOS FPS

PD&MS Group, an Aberdeen-based leading Engineering, Procurement, Construction and Commissioning (EPCC) and Operations & Maintenance company, has been awarded a multi-million-pound contract by INEOS FPS, for the provision of engineering, procurement, construction and management services (EPCm). The contract term is for three years with options to extend by a further two years and is expected to create around 200 job

Chosen as INEOS FPS’ long-term strategic partner, PD&MS will deliver comprehensive EPCm services across projects, minor modifications, repair and maintenance, turnarounds and offshore walk-to-work campaigns at the Unity Platform.

The Forties Pipeline System (FPS) is a strategic UK infrastructure that transports and processes oil and gas from around 80 offshore North Sea fields, for delivery to international markets.

Simon Rio, Chief Executive Officer at PD&MS, commented:

“We are delighted to be chosen by INEOS FPS as their strategic partner working with them as part of their assets’ operations, modification and enhancement program. We will be focussed on driving efficiency, effectiveness and safe delivery across work scopes. This partnership reinforces our position as a leading EPCC provider and highlights the strength

of our market-leading Integrated Services capabilities within the wider RSK Group.

Our shared values, culture, and collaborative approach have been key to securing this award, and we are excited to play a pivotal role working with INEOS FPS to support this vital UK infrastructure.”

Ewan MacAngus, Operations Director at INEOS FPS, added:

“This contract with PDMS is perfectly aligned with INEOS FPS’s strategy of fostering longterm relationships with highly competent partners. PDMS were the stand out company in our exhaustive tender process where their ability to offer tangible project efficiencies stood out significantly. We are excited at the prospect of collaboratively delivering safe, high-quality and sustainable solutions across our asset footprint with PDMS in the months and years ahead.” 

Wood wins significant decarbonisation project in the Middle East

Wood, a global leader in consulting and engineering, has secured a contract worth around $17 million from a leading petrochemical company in the Middle East to improve efficiency and reduce emissions on a process manufacturing plant.

Under this 18-month contract, Wood is providing consultancy and engineering services, process technology and specialist equipment to enhance operations by adding a new heat recovery unit to an existing process plant. Wood’s solution is estimated to drive a reduction of around 110 kilo-tonnes per annum of CO2 emissions, the equivalent of removing 22,000 cars from the road.

As part of the scope, Wood delivered a series of innovative feasibility studies and an early engineering package, designing a complex system to effectively collect the high-temperature flue gas and deliver it to a waste heat recovery transfer system to generate mediumpressure steam.

Daniel Carter, President of Technical Consulting at Wood, said: “Optimising process technologies and equipment can deliver quick and immediate wins, offering a cost-effective way to significantly reduce emissions in industrial facilities.

“With the Middle East continuing to play a leading role in driving global decarbonisation, we’re focused on identifying the most promising and practical decarbonisation pathways for our clients to achieve their carbon reduction goals without compromising their efficiencies or cost drivers.” 

Shell Awards $1.98 Billion Contracts to Nigeria’s Local Firms in 2023

Shell plc, a British multinational oil and gas company headquartered in London, has announced that its units in Nigeria awarded remarkable $1.98 billion worth of contracts to Nigeria’s companies in 2023. This figure represents a 3% increase compared with 2022, marking a steady commitment by the British oil giant to foster local business development and strengthen its operations in the nation of West Africa

The key entities behind these significant contract awards were the Shell Petroleum Development Company of Nigeria Ltd. (“SPDC”), Shell Nigeria Exploration and Production Co. Ltd. (“SNEPCo”) and Shell Nigeria Gas. The contracts cover various aspects of Shell’s operations in the country, including oil exploration, production and gas operations. By collaborating with Nigeria-registered companies, Shell continues to support the country’s industrialization, ensuring that the benefits of the oil industry are shared more equitably across the nation.

Empowering Local Companies and Promoting Expertise

Shell’s focus on Nigeria’s businesses is a deliberate effort to enhance local capacity, strengthen financial stability and improve operational expertise. According to Shell’s recent press release, many of the companies benefiting from these contracts have expanded their operations and improved overall business strength. This growth, both in terms of expertise and financial health, has allowed these local firms to take on even more complex and large-scale projects, fueling Nigeria’s progress in the global energy market. 

Kent Awarded 3-Year Global EPCm Framework with bp

London, UK, 4th December 2024 – Kent, a leading engineering and project services company, is pleased to announce it has been awarded a three-year global Engineering, Procurement, and Construction Management (EPCm) framework contract by bp (P&O Projects). This contract includes options for two additional 2-year extensions and positions Kent as a key partner to bp in delivering world-class project services across bp’s global asset portfolio.

The framework covers the full scope of EPCm services, supporting bp’s asset lifecycle, from small and large projects to minor modifications. The framework will encompass bp’s global portfolio of offshore and onshore projects.

This prestigious award was negotiated as a result of Kent’s longstanding relationship with bp and builds upon their growing association. The new framework sits alongside Kent’s existing contracts with bp, including concept and FEED Engineering services and a global commissioning framework. This contract reinforces bp’s commitment to its energy goals worldwide.

John Gilley, CEO of Kent, commented: “This award is a significant milestone that underscores our strength and global reach in project delivery and highlights the trust and valuable relationship we have built with bp. This framework is perfectly aligned with Kent’s strategy of fostering long-term relationships and we are excited to continue supporting bp in their energy journey by delivering high-quality, safe and sustainable solutions across their asset base.” 

Australia’s strategic strengths and growth opportunities in decommissioning

Decommissioning is capital intensive and needs detailed planning and execution. Decommissioning activity also needs a range of specialist and often very large offshore vessels and rigs. As in other jurisdictions, most costs in a decommissioning project occur offshore.

These costs include well plugging and abandonment as well as removing large offshore facilities, like jackets and topsides, from the marine environment (Norwegian Offshore Directorate 2019). To undertake this work, an experienced workforce, the right vessels available at the right time, and a culture of safety and environmental stewardship are needed. Australia is well positioned to scale up a decommissioning industry because of the strength of our existing offshore industries. Upstream activities like planning and well plugging and abandonment are key strengths. Manoeuvring and installing large-scale offshore infrastructure, as well as operating safely and efficiently in the marine environment, are areas of competitive advantage.

In these areas, Australia can apply its already significant experience and expertise to support a sustainable decommissioning industry (KPMG 2023). Other areas represent opportunities to grow Australia’s capabilities, such as through increased innovation in end-of-life material management.

Workforce

Australia has a skilled domestic workforce with extensive experience in the oil and gas industry. Research commissioned for this roadmap demonstrates the majority of the existing workforce can re deploy and re-skill for decommissioning projects to support Australia’s energy transition (CSIRO 2024a). However, it may be difficult to attract and keep a workforce due to competition with an emerging renewables sector (KPMG 2023).

Vessels

Australia is distant from most global decommissioning markets where there are vessels and specialty equipment (KPMG 2023). Australia does not host the vessels for doing heavy decommissioning offshore and must import them. Local availability for heavy lift and specialist vessels is unlikely to be a strategic opportunity and can be best managed through importation and collaboration. However, there are opportunities for the domestic workforce to crew and support these activities (CSIRO 2024a). Our limited market for offshore decommissioning vessels at present makes it costly to bring these assets into Australian waters for uncoordinated campaigns or single decommissioning projects.

Infrastructure

Offshore decommissioning in Australia will be an inherently regional activity, with work clustered in south-east and north-west Australia. The south-east of Australia will also host significant offshore wind generation in future. Constructing offshore renewables could overlap with decommissioning and increase competition for infrastructure and capability, including ports, which requires careful management and coordination. There is no port perfect for all decommissioning activity types, which may necessitate modifications in future to service decommissioning demand.

Waste management and recycling

Australia has a domestic recycling industry that can play a major role in the waste management phase of offshore decommissioning. It also has a mature concrete recycling market that services the construction and demolition industries.

Australia’s recycling and waste management industries are generally well placed to manage decommissioned materials appropriately. However, there are some critical knowledge gaps that, if addressed, could improve outcomes. This includes innovation on the impact of contaminants on the environment and ecosystems, possibilities to develop new recycling pathways and technologies, and more efficient cleaning and waste management processes. 

US Driller Seeks Court to Block Demands for $250M Decom Collateral

W&T Offshore, an independent driller operating in the U.S. Gulf of Mexico, has asked a federal judge to block insurance companies’ demands for $250 million in additional collateral for taking apart old oil infrastructure.

The offshore drilling industry faces mounting pressure to provide bonds for decommissioning oil and gas infrastructure in federal waters. The Federal Bureau of Ocean Energy Management (BOEM) in June enforced a final rule that amended its financial assurance regulations in a bid to ensure the industry covers decommissioning costs, not the taxpayer.

The BOEM estimates offshore drillers would collectively pay just under $7 billion as a result in new supplemental financial assurances to cover the potential costs of decommissioning activities.

Decom Engineering

ends

2024 on a high with £2 million contract wins

Decom Engineering (Decom) is set to finish 2024 on a high with the completion of several key contracts in the UK North Sea, Gulf of Mexico and South America worth an estimated £2 million.

The UK-based company has cemented its reputation as the leading provider of decommissioning subsea cutting and asset recovery services showcasing its ability to deliver innovative solutions for complex offshore projects.

In the UK North Sea, Decom recently completed a significant conductor removal campaign, further solidifying its capability to deliver safe and efficient decommissioning solutions. The success of this operation highlights Decom’s expertise in addressing technical challenges across diverse offshore environments.

Offshore Western Australia, Decom is set to deploy its custom-built Tracksaw to complete linear cuts in areas of limited access and remove excess webbing to allow the safe recovery of a disconnectable turret mooring on an offshore field.

Additionally, Decom is preparing to complete another project in Australia which will involve deploying its patented Chopsaws to deliver fast and consistent cutting of mooring chains on the seabed.

Decom is also scheduled to complete a challenging project in Exmouth Gulf, Western Australia, performing 850 cuts on an 8” multi-layer flexible flowline over a 30-day window.

Decom Engineering managing director, Sean Conway, said: “Offshore Australia has become an increasingly important market for our cutting technologies and the diversity of these projects underlines the flexibility our Chopsaws can offer a range of clients.

As of June 2023, more than 2,700 wells and 500 platforms were overdue for decommissioning in the Gulf of Mexico, according to the U.S. Government Accountability Office.

In the lawsuit, filed on Wednesday in the U.S. District Court for the Southern District of Texas, W&T Offshore asked Judge Keith Ellison to declare that the insurers have colluded to damage the company by jointly demanding additional collateral and premiums.

The company claims the insurers used BOEM’s final rule to demand additional collateral for surety, for which the operator has already paid premiums.

“We have worked with each client over many months to devise tailored solutions which addresses their unique technical and logistical challenges. The relationships we have built up with major operators in the region gives us confidence that Australia will continue to be a strategic region which will support our growth in 2025 and beyond.”

In the Gulf of Mexico, Decom is preparing for a 40day campaign on a major Tension Leg Platform. The C1-24 Chopsaw will be deployed to severe 24” tendon sections on the platform decommissioning project, overcoming complex challenges such as tension and internal structures.

The company is also optimising its Chopsaw tool range with the development of a lightweight variant (C1-16UL). This bespoke tool will be deployed during a 45-day campaign in the Shenandoah Field, cutting studless mooring chains in less than 10 minutes and incorporating a linked retention system to secure severed sections.

In South America, Decom is gearing up for a 10-month project to cut multiple 120mm link mooring chains on an offshore installation. A specially designed C1-16 Chopsaw has been developed to meet project demands, allowing chain cutting without blade changes or tool recovery.

Sean Conway added: “It is encouraging to finish 2024 so strongly. The diversity of the projects we have lined up for 2025 is a testament to the innovative approach that is central to how we work with clients.

“These upcoming contracts in the UK North Sea, Australia, North America and South America, alongside our growing portfolio of work completed offshore Africa and Gulf of Thailand, provide a solid foundation for our continued growth. We will support that with ongoing investment in R&D to expand our technology and drive revenues.” 

Houston-based W&T Offshore did not immediately provide a comment.

Endurance Assurance Corp and Lexon Insurance Co, both named in the suit, did not immediately respond to requests for comment.

Opponents said BOEM’s final rule would disproportionately affect smaller companies that lack investment grade ratings or sufficient proven oil reserves. Oil majors are more likely to have large reserves, or meet credit criteria exempting them from putting up more money to cover potential future decommissioning. 

STATS & ANALYTICS PROVIDED BY

Offshore Field Development Update

Offshore O&G-related EPC contract award value year-to-date is estimated at US$45.6bn (excluding letters of intent), with an additional US$10bn of EPC contract awards still anticipated for the remainder of 2024. During the period under review, BP sanctioned its US$7bn Tangguh CCUS project, which will capture roughly 15mmpta of CO2 in its first phase and inject some of it back into the natural gas reservoir at Ubadari for enhanced recovery. Saipem confirmed the EPCI contract award with its consortium partner PT Meindo Elang Indah valued at US$1.2bn, following the project's FID announcement. Offshore Brazil, OneSubsea was awarded a contract to manufacture and supply two subsea injection systems valued at US$134.5mn to serve the P-74 and P-75 FPSO units installed at Petrobras' Buzios development.

Westwood anticipates an additional 16 subsea tree unit awards in the final weeks of 2024, driven by projects such as Northern Endurance partnership's CCS project in the UK North Sea, which had its FID announced on 10 December. Overall, Westwood anticipates 2024 subsea tree awards to close at 263 units, 18% lower than our January outlook, given project sanctioning delays resulting from supply chain inflationary pressures and a softening of oil prices in 2H 2024, resulting from a weaker oil demand outlook. Two FPS units are still expected to be sanctioned before the end of the year, including BP's Kaskida production platform in the US GoM. Contract confirmation for the FLNG unit to be deployed at Eni's Coral Norte is also pending, however a delay until 2025 is highly likely.

Offshore Drilling Rig Update

The global committed jackup count decreased by six to 405 units in November. Marketed available and cold-stacked jackup counts now stand at 40 and 55 respectively, with marketed committed utilisation and total utilisation at 91% and 81%, respectively. During the month, a total of five new contracts were awarded, amounting to 1,773 days (4.9 rig years) of backlog added. Pertamina Hulu Energi ONWJ has exercised its options for additional work with the PV Drilling II offshore Jakarta, Indonesia. The extension is for three years starting December 2025.

The global committed semisubmersible count decreased by two to 63, with 13 available and 12 cold-stacked rigs remaining in the fleet. During the month, marketed committed and total utilisation remained at 83% and 71% respectively.

The Lone Star has been awarded a 400-day contract by Brava Energia to drill four wells from October 2025 through November 2026, at a dayrate of $325,000.

Finally, the global drillship count dropped to 78 units during the month, leaving 12 marketed rigs available plus 13 cold-stacked units. Marketed utilisation and total utilisation dropped to 87% and 76%, respectively. No new fixtures were recorded in November. Atlantic Zonda has been undergoing shipyard modifications in Brazil since November 2024 and will commence drilling for Petrobras in January 2025. West Capella arrived in Busan, South Korea on 9 December.

Offshore Wind Update

Since the last update, Siemens Gamesa was awarded a contract for the supply of 64 SG 14-236 DD (15.0 MW Power Boost) turbines at the 960MW East Anglia Two wind farm. The value of the contract is GBP1 billion (US$1.28bn) and the turbine blades will be manufactured at Siemens Gamesa's facility in Hull, UK.

Nexans has also been awarded a contract for the export cables at East Anglia Two. Nexans will be responsible for supplying and installing 100km of 275kV offshore cables and 55km of onshore cables. Cable installation is scheduled to occur in 2027 and 2028. The cables will be manufactured at Nexans facilities in Halden, Norway, and Charleroi, Belgium.

Dominating headlines was news that no bids were placed in Denmark’s lease tender for the rights to develop the three sites available via the 3GW Nordsøen I (North Sea I) lease auction. The tendering procedure expired on 5 December. A further three offshore wind sites are still on offer under this tender and the deadline for bids for these three sites is 1 April 2025.

Finally, TotalEnergies has put on hold the Attentive Energy One wind farm in the US, however the company has confirmed its still progressing its Attentive Energy Two project. TotalEnergies was awarded an OREC contract with New Jersey for Attentive Energy Two in January 2024. The project still needs to seek approval of its Construction and Operations Plan (COP) from BOEM, which will be subject to appointees of President Trump from January 2025.

Westwood Global Energy Group are specialist providers of detailed market intelligence for the offshore energy sector, covering; offshore rigs, production facilities, subsea equipment, subsea services, offshore marine and offshore renewables and power.

www.westwoodenergy.com

Travel Trends in 2025

World Future Energy Summit

14-16 Jan 2025

ADNEC, Abu Dhabi

MEOS Manama

4-6 February 2025

Manama, Bahrain

E-world energy & water 11-13 February 2025

Essen, Germany

India Energy Week 2025 11-14 February 2025

Yashobhoomi, Delhi

KEY – The Energy Transition Expo

5-7 March 2025

Rimini Exhibition Centre, Italy

Future of Utilities 19-20 March 2025

SugarFactory, Amsterdam

As we enter the new year, 2025 will present new opportunities for growth, to collaborate across sectors and throughout the supply chain, and to drive the energy industry forward.

The key to unlocking these new opportunities? Breaking down barriers and strengthening our ability to get together to share ideas and work together for a better future.

Naturally, with energy projects, discussions, and assets taking the workforce to international locations, travel will continue to play a critical role in the supporting the industry achieve its goals. Whether C-Suite executives travelling for meetings, sales managers attending events, or the men and women working on rigs and vessels powering the industry and the communities it serves, logistics are unavoidable. How and where we source energy is set for change, as is travel.

A recent survey found that almost 50% of businesses in EMEA regions are planning to increase travel plans in 2025. With this increase in demand, the latest travel management policies, strategies, and technologies will be integral in maximising the efficiency of corporate travel wherever the new year takes you.

Recovery

After four years of pandemic-induced volatility where companies navigated through fluctuating costs and market conditions, there is an end in sight. A report from the Global Business Travel Association (GBTA) points to 2025 being the year of stabilisation where the travel market can rebound after a challenging period.

The anticipation of a more stable market aligns with reports of an increase in travel plans. For the energy industry, this means greater opportunities to travel, expand our networks, explore new opportunities to collaborate, and tackle challenges as a united industry. An increased in travel allows all those in the supply chain to visit new regions and markets and forge new partnerships that can support business objectives. However, an increased focus on travel also comes with an increased responsibility for the workforce and the environment.

Responsible Travel

If the frequency of travel is to increase, so to must the considerations for changing Net Zero legislation. Companies are used to navigating pressures surrounding sustainability efforts and that will continue this year. Across travel industry reports and surveys, sustainability is often cited as a top priority, and we have seen an increase in actions being taken to reflect this.

For the energy industry, a more responsible approach to travel is non-negotiable to remain on the path to Net Zero by targeting and successfully reducing Scope 3 emissions. But support from travel experts is needed to maintain that journey so travel managers will continue to play an integral role in creating carbon reduction strategies that support organisation’s overall goals - without sacrificing necessary travel. A poll from GBTA found that while sustainability is a focus, travel managers cite complexity as a barrier to achieving goals. Expertise combined with technology is a must.

Technology & Innovation

Technology will help many across the industry streamline their approach to sustainability while enhancing the customer experience. Further investment in travel technology has led to greater innovation with new technologies emerging – many of which enhanced by AI.

For sustainability, this will allow operators to track, manage, and, with platforms such as ATPI Halo, even offset Scope 3 emissions. These technologies can source sustainable alternatives to lower emissions while pinpointing eco-friendly accommodation and investing in carbon offset programmes.

Alongside being a positive for sustainability efforts, innovative travel technologies also benefit the customer in several ways. With an increased adoption of AI, the travel experience is only getting better thanks to enhanced capabilities including personalised itineraries that are bespoke to each traveller and incorporate their preferences. Meanwhile, for travel managers and admin assistants, platforms such as ATPI’s CrewHub will focus on streamlined crew management to support the transfer of the workforce to and from assets.

2025 will present exciting opportunities to make the most of travel across the energy industry, facilitated with the support, expertise, and technology of leading TMCs like ATPI.

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