Issue 91_Decom_ISSUU

Since its founding in 1972, JW Automarine has established itself as the leading manufacturer and supplier of PVC and PU products, specialising in marine underwater airbags and technical solutions for salvage and deployment operations.

Recognised as the original innovator in the field, JWA pioneered the Water Weight Load Test Bag market, with its signature Yellow Bags establishing a global industry standard.

Welcome to the April edition of ‘OGV Energy Magazine’ where this month we are exploring the theme of Decommissioning

With the publication of the ‘Business Outlook report’ from Offshore Energies UK launching as we go to print, the decisions the government make will on energy policy will impact the entire country and the decommissioning sector has a hugely important part to play in shaping that future.

A big thank you to our front cover partner Dräger this month and you can read all about how their mobile gas monitoring technology is helping the sector to stay safe on pages 4-5.

We are also delighted to welcome contributions from Elemental Energies, Three60 Energy, Zenith Energy, J+S Subsea, PTS Services and Sureclean

The rest of this month’s magazine as always provides you with a review of the Energy sector in the North Sea, Europe, Norway, Middle East and the US, along with industry analysis and project updates.

The critical role of mobile gas monitors in decommissioning

As aging energy and industrial assets reach the end of their lifecycle, the safe decommissioning of this infrastructure ensures that hazardous materials are safely removed, reducing risks to human health and the surrounding environments

Decommissioning is a broad term that covers the dismantling and removal of various parts of the energy and industrial chain, including offshore platforms, refineries, petrochemical plants, and storage facilities. These sites often contain residual hydrocarbons, volatile organic compounds (VOCs), hydrogen sulphide (H2S), carbon monoxide (CO) and other hazardous substances that can be toxic to humans, animals and the environment. Without proper monitoring, these gases pose significant risks, including explosions, asphyxiation, and long-term environmental contamination.

A critical part of the energy transition and vital to delivering on ambitions for a just transition for workers, decommissioning is an intricate, high-risk operation that requires meticulous planning, stringent safety measures, and adherence to regulatory frameworks and professional standards.

Ensuring worker safety and environmental protection during this process is paramount, and one of the most critical aspects of hazard mitigation is the effective use of mobile gas monitors. Unlike fixed monitoring systems, mobile gas detectors offer flexibility and adaptability, ensuring that personnel can monitor gas concentrations at multiple locations throughout the decommissioning process –including within confined spaces. Using innovative technology and leading digital solutions, monitors provide real-time detection of these threats, allowing workers to respond swiftly to potential hazards.

Stork, a specialist in delivering asset integrity, maintenance, and modifications solutions across a range of energy and industrial sectors, is one of a number of companies that frequently undertakes offshore confined space vessel cleaning.

Mercury monitors, for example, are not only expensive but also require frequent calibration, which can be time-consuming on decommissioning projects. Additionally, the reliance on thirdparty calibration services further complicates the process, adding delays, operational inefficiencies and additional budget.

Traditionally, monitoring for dangerous gases in restricted areas offshore requires multiple devices, including separate and specialist monitors for detecting risks of mercury and benzene, a hazardous carcinogen. This fragmented approach leads to operational challenges, particularly in confined space operations, where efficiency and accuracy are critical.

Stork, in need of a more streamlined and efficient solution - one that could enhance productivity and worker safety while reducing costs and calibration complexitiesturned to Dräger and its innovative Dräger X-act® 7000 analysis system, a cuttingedge solution that significantly enhances the monitoring of hazardous gases in confined spaces.

This system, which utilises Dräger MicroTubes and an optoelectronic analysis device, provides laboratory-quality analysis on-site, eliminating the need for costly and time-consuming lab tests.

Unlike many other gas detection systems, the Dräger X-act® 7000 requires no calibration, as each MicroTube comes preloaded with RFID calibration data, eliminating the need for manual adjustments and reducing downtime.

All test results, including time and location data, are automatically stored in the internal data logger and can be accessed and analysed through Dräger CC Vision software, ensuring full traceability. Additionally, the disposal process for the MicroTubes is simpler and safer compared to traditional methods and accurate measurements of hazardous gases ensured compliance with safety regulations.

With its ability to detect gases at extremely low parts-per-billion (ppb) concentrations, the Dräger X-act® 7000 offers an exceptional level of sensitivity, making it a reliable choice for accurate gas analysis.

By integrating this advanced technology into its decommissioning operations, Stork has improved workplace safety, streamlined operations, and ensured compliance with workplace exposure limits.

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Discussions are ongoing, Serica said, noting that it is currently envisaged that the possible transaction will be structured as an all-share offer by EnQuest for Serica by way of a reverse takeover under the UK Listing Rules.

“Discussions remain ongoing between the Boards of EnQuest and Serica, and a further announcement will be made in due course,” EnQuest said.

“There can be no certainty that an offer will be made, nor as to the terms on which any offer will be made,” EnQuest added.

Meanwhile, Serica Energy announced that the US Treasury’s OFAC License and secondary sanctions assurance relating to the Rhum field in the UK North Sea has been renewed for another two years.

Serica Energy, which owns 50 percent in the gas and condensate field Rhum, needs a US licence because Iranian Oil Company has a 50-percent interest in Rhum.

The licence, which was previously extended by two months to 31 March 2025, has now been renewed, with a new two-year License ending on 28 February 2027.

Free cash flow generation is expected at $2.0-4.0 billion.

Harbour Energy will also aim to reduce debt by $500 million to $1.0 billion, in line with a conservative approach to balance sheet management. The company noted the potential for material additional shareholder returns via share buybacks.

“Through successful acquisitions, we grew from zero to more than 450 kboepd in eight years, returning $1.2 billion to our shareholders in the last three years alone,” chief executive officer Linda Cook said.

“Value-driven M&A will remain key to our strategy, alongside investments in our existing resource base and selective divestments, as we continually high-grade our portfolio,” Cook added.

2024 was a transformational year with the completion of the Wintershall Dea transaction, our fourth significant transaction since 2017.

The Rhum field has benefited from an OFAC License continuously since 2013.

In March, Harbour Energy plc updated investors on its strategy to create value by building a global, diversified oil and gas company focused on cash flow and shareholder distributions.

Harbour Energy expects its production to average around 450,000 boepd in the 2025-2027 timeframe, with stable operating costs of less than $15 per barrel of oil equivalent (boe). Total annual capital expenditure is seen at less than $2.0 billion in 2026 and 2027, down by 25 percent on 2025 levels.

Commenting on the 2024 performance, Cook said that “2024 was a transformational year with the completion of the Wintershall Dea transaction, our fourth significant transaction since 2017.”

Orcadian Energy plc said that after completing the acquisition of HALO Offshore UK Ltd in December 2024, it has agreed the sale of a 50-percent interest in HALO to The Independent Power Corporation PLC (IPC).

“Having closed the acquisition of HALO in December we are delighted to have brought IPC in as a 50% partner in HALO which we intend to grow into a gas producing company just as quickly as we can,” Orcadian’s chief executive Steve Brown said.

“We believe that 2025 will see us well on the road to being a production company and graduating from our current pre-development status.”

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Europe Energy Review

By Tsvetana Paraskova

A transformative acquisition in Norway’s North Sea, several oil and gas discoveries offshore Norway, the UK’s continued efforts to boost clean energy rollout, and a number of innovative green energy projects featured in Europe’s energy sector in recent weeks.

Oil & Gas

Norwegian oil and gas operator DNO ASA has reached an agreement to acquire 100 percent of the shares of Sval Energi Group AS from HitecVision for a cash consideration of US$450 million based on an enterprise value of US$1.6 billion.

Sval Energi’s assets are complementary to DNO’s North Sea portfolio and will add scale and diversification to solidify the company’s position as a leading listed European independent oil and gas company.

The deal will boost DNO’s global net production by two thirds to around 140,000 barrels of oil equivalent per day (boepd) on a 2024 pro forma basis and proven and probable (2P) reserves by 50 percent to 423 million barrels of oil equivalent (boe). The transaction will quadruple North Sea production to around 80,000 boepd, propelling DNO to the upper ranks of Norwegian Continental Shelf players.

“This is a rare opportunity to acquire a portfolio of high-quality oil and gas assets on the Norwegian Continental Shelf,” said DNO’s Executive Chairman Bijan MossavarRahmani.

“Given low unit production costs and limited near-term investment requirements, the Sval Energi portfolio is highly cash generative and will help underpin development of the numerous discoveries we have made in Norway recently,” he added.

Equinor and its partners, Okea and Pandion Energy, have proven gas and condensate in the Mistral Sør exploration well in the Halten area in the southern part of the Norwegian Sea.

Preliminary estimates indicate that the discovery contains 19-44 million barrels of recoverable oil equivalent.

“Norwegian gas is in high demand and is crucial to Europe’s energy security. That’s why it’s important for us to continue exploring and making new discoveries so we can maintain a high level of deliveries,” said Grete B. Haaland, Equinor’s senior vice president for Exploration & Production North.

Vår Energi has discovered oil in the Zagato prospect, directly north of the Goliat field in the Barents Sea, the Norwegian Offshore Directorate said.

Preliminary estimates place the size of the discovery at between 15 and 43 million barrels of recoverable oil equivalent.

The licensees will assess the discovery together with other discoveries and prospects in the vicinity, with a view towards a potential development tied back to existing infrastructure on the Goliat field.

In the Mediterranean, TotalEnergies and Eni have signed an agreement with Cyprus and Egypt for the export of gas from the offshore Block 6 in Cyprus through Egypt.

The agreement provides a framework allowing the gas from the Cronos field offshore Cyprus to be processed in the existing Zohr facilities offshore Egypt and then liquefied in the Damietta LNG plant in Egypt, for export to European markets.

Following the signing of the agreement, the partners of the Block 6 offshore Cyprus will now proceed with the Cronos Development and Production Plan, in close collaboration with Cyprus authorities.

Naftogaz of Ukraine and Poland’s ORLEN have signed a memorandum of cooperation in the LNG sector. The document formalises a long-term strategic partnership between the companies, enabling Ukraine to create a more diversified gas supply system.

“Ukraine has a robust gas transportation system and Europe’s largest underground storage facilities, offering unique opportunities for LNG market expansion,” commented Roman Chumak, Naftogaz Ukraine’s Acting Chairman of the Board.

“Partnering with ORLEN strengthens energy security, diversifies supply routes, and accelerates Ukraine’s integration into the European gas market.”

Low-Carbon Energy

The UK government has launched a consultation on a plan to unleash the North Sea’s clean energy future and ensure prosperous and sustainable transition for oil and gas.

The plan is aimed at backing industry to make the North Sea a world-leader in offshore industries, such as hydrogen, carbon capture, and wind, as part of the government’s clean energy superpower mission.

“A future focused on offshore wind isn’t just cleaner - it provides a more stable energy system for billpayers as we will be less exposed to volatile international fossil fuel prices,” said Dan McGrail, Chief Executive, RenewableUK.

“Offshore wind also offers opportunities for skilled workers from other industries to transfer into this dynamic and innovative sector,” McGrail added.

The UK government is also consulting on proposals to provide greater certainty to clean energy investors and a better deal for consumers, including relaxing the eligibility criteria on planning consent for fixed-bottom offshore wind, changing how offshore wind budgets are set and published, and increasing

USA Energy Review

By Tsvetana Paraskova

The new policies of the Trump Administration, the surge in power demand from data centres, and rising job numbers in oilfield services featured in the US oil and gas industry in the past month.

US Natural Gas Output Set to Rebound

Higher natural gas prices are set to incentivise US producers to increase natural gas production in 2025 and 2026, following steady output in 2024, the US Energy Information Administration (EIA) said in its monthly ShortTerm Energy Outlook (STEO) for March.

EIA expects US dry natural gas production to increase by 2 percent in both 2025 and 2026, after having levelled off in 2024 as natural gas prices fell to historic lows. With the rise in natural gas prices, production will rise to 105 Bcf/d in 2025.

Higher natural gas prices will incentivise more drilling in the natural gas-producing Appalachia and Haynesville regions, and rising crude oil production will result in more associated natural gas production in the Permian region, according to the EIA estimates. Moreover, pipeline takeaway capacity additions in the Northeast and Permian regions will also support increased production. Last but not least, strong global demand for LNG will also support higher production compared with 2024. Next year, US dry natural gas production is set to average 107 Bcf/d, per EIA’s latest forecast.

Higher natural gas consumption this winter has drawn down working inventories at US

sites more than in the previous years. At the end of the winter season, gas stocks are expected to be about 10 percent lower than the five-year average.

Due to the lower stocks, the EIA has now increased its Henry Hub price forecast to average around $4.20/MMBtu in 2025, which is 37 percent higher than the forecast in October before the winter season began.

The EIA now forecasts that the Henry Hub natural gas price will average $4.50/MMBtu in 2026 as global LNG demand grows and the two new US LNG export facilities— Plaquemines LNG Phase 1 and Corpus Christi Stage 3—ramp up production.

China’s tariffs on US LNG imports, enacted in February 2025, will “have little to no effect on U.S. LNG exports because destination-flexible U.S. LNG cargoes can be routed to other global markets,” the EIA said.

Natural Gas Could Be A Winner in the US Power Demand Surge

With the Trump Administration’s threat to dismantle all, or at least some provisions, in the Inflation Reduction Act (IRA), natural gas could become the favourite to fill the gap in supporting power demand growth, Wood Mackenzie’s analysts say.

If renewables projects stall, coal plant retirements will be deferred but that won’t be enough to meet demand growth, notes Chris Seiple, Vice Chair, Power and Renewables, at WoodMac.

“Nuclear and geothermal are longer-term solutions. That leaves gas in the driving seat, so to speak, and by some distance,” Seiple said.

“Existing gas plants will be the biggest beneficiaries as they are best placed to capture some of the new demand growth from their excess capacity during some hours.”

Existing gas plants will not be able to meet all the demand, so new gas-fired capacity will still be needed, according to WoodMac.

Additional gas capacity for the power generation sector is highly likely to put upward pressure on US natural gas prices, Seiple said.

“The scale of America’s energy need is breathtaking, and we have the opportunity to power that future,” API President and CEO Mike Sommers said in an address to the Economic Club of Pittsburgh.

“The electricity AI will need is unprecedented. By one estimate, if we want to keep the bulk of AI on American soil, we’ll need to dedicate about 51 gigawatts just to data centers. That’s equal to 103 percent of all the generation capacity in Pennsylvania.”

The scale of America’s energy need is breathtaking, and we have the opportunity to power that future

“A combination of faster roll-out of gas plant and the anticipated LNG project final investment decisions will put upward pressure on US prices – and, by implication, global LNG prices.”

As data centres reshape the US power sector, natural gas emerges as a critical power source to supply firm and flexible power within an immediate time frame, Rystad Energy says.

The inventory of planned gas generation projects within the utility sector – excluding independent power producers – has increased from 6 gigawatts (GW) in late 2023 to a staggering 17.5 GW currently, the highest since 2017, according to data from the energy research firm.

US supermajors ExxonMobil and Chevron are already planning and building gas plants to take advantage of the expected power demand boom.

In January, Chevron and investment firm Engine No. 1 announced the formation of a partnership to build a new company to develop scalable, reliable power solutions for US-based data centres running on US natural gas.

“By using abundant domestic natural gas to generate electricity directly connected to data centers, we can secure AI leadership, drive productivity gains across our economy and restore America’s standing as an industrial superpower,” said Chris James, founder and chief investment officer of Engine No. 1.

The American Petroleum Institute (API) outlined policy solutions to meet the surge in US electricity demand driven by the AI revolution.

Over the past seven years, US electricity demand has grown by 2.5 percent in total. Over the next seven years, it is projected to jump by 25 percent, Sommers added.

“We need bureaucrats to quit telling Americans what they can drive. Americans need to decide what is best for them to drive to school and work,” API’s president said.

“To rebuild our failing infrastructure, we need sensible permitting reform. We need to green-light LNG exports and process pending applications. We need to open up leasing, onshore and offshore, and ensure the American people’s federal lands and waters are working for them.”

“Americans want our leaders to channel the proactive, pioneer spirit that made us the greatest nation and economy in world history,” Sommers said.

“If we get energy wrong, national security is put at risk. Living standards decline. Pennsylvania workers lose their jobs. New inventions are snuffed out before they scale,” the API official added.

Jobs Grow in US Energy Services Sector

The US energy services sector saw an increase in the number of jobs in February, the Energy Workforce & Technology Council said in March in its February 2025 jobs report.

Total jobs in the sector increased to 639,743 in February 2025, reflecting a gain of 4,170 positions from January, according to preliminary data from the Bureau of Labor Statistics (BLS) and analysis conducted by the Energy Workforce & Technology Council.

“The energy services sector continues to be a driving force for economic progress,” said Energy Workforce President Molly Determan.

“As we work to unleash American industry and prioritize domestic production, the industry is showing growth. We are optimistic about the future of employment across the industry,” Determan noted.

“This momentum reflects our workforce’s important role in securing American energy security and economic prosperity.” 

bp has reached agreement on all contractual terms with the Iraqi Government to invest in several giant oil fields in Kirkuk providing for the rehabilitation and redevelopment of the fields, spanning oil, gas, power, and water with potential for investment in exploration. The agreement is subject to final governmental ratification.

Following endorsement from the Iraqi government, bp will work closely under the guidance of the Government of Iraq in setting up the new operator, which will be an unincorporated organization comprising predominantly personnel from the North Oil Company (NOC) and North Gas Company (NGC), but also with secondees from bp. The new operating organisation will take over operations at Kirkuk from NOC. Subsequent to this agreement, bp expects to form a standalone incorporated joint venture to hold its interests in the operator.

The wider resource opportunity across the contract and surrounding area is believed to include up to 20 billion barrels of oil equivalent, bp said.

“This opportunity is fully in line with our priority of pursuing new growth opportunities for bp as we strengthen and high-grade our portfolio across the world,” bp executive vice president William Lin said.

“This agreement builds on our longstanding and strategic relationship with the Government of Iraq and delivers access to a material new resource opportunity, within one of the world’s most prolific hydrocarbon provinces.”

bp also announced the start of production from the second development phase of the Raven field, offshore Egypt. The phase involves the subsea tieback of additional Raven infill wells to its existing onshore infrastructure as part of the West Nile Delta (WND) project. bp, the operator, holds an 82.75-percent stake in the project, while Harbour Energy owns the remaining 17.25 percent.

The new wells are expected to produce approximately 220 billion cubic feet of gas and 7 million barrels of condensate.

“The focus of the Raven Infills project has been to fight natural decline and increase production while maximizing our existing infrastructure to meet Egypt’s domestic market demand at pace,” said Nader Zaki, bp Regional President for the Middle East and North Africa.

Raven Infills is in line with bp’s drive to deliver as a simpler, more focused, highervalue company by maximizing production from existing assets and optimising resource efficiency.

From the United Arab Emirates (UAE), Abu Dhabi National Oil Company (ADNOC) announced that it had agreed with Austriabased energy firm OMV terms of a binding Framework Agreement regarding the proposed combination of shareholdings in Borouge plc and Borealis AG.

ADNOC and OMV have also agreed that upon completion of the combination, Borouge Group International will acquire Nova for $13.4 billion including debt, further expanding its footprint in North America. The acquisition would create a new $60+ billion global polyolefins champion, set to be the world’s fourth largest by nameplate production capacity, ADNOC said.

In yet another LNG deal, ADNOC has signed a Sales and Purchase Agreement (SPA) with Osaka Gas, one of Japan’s largest utility companies, for the supply of up to 0.8 million

tonnes per annum (mtpa) of LNG from ADNOC’s lower-carbon Ruwais LNG project in Abu Dhabi.

The agreement with Osaka Gas is the fourth one for Ruwais LNG, which is scheduled to start commercial operations in 2028.

“This agreement with Osaka Gas reinforces our long-standing energy partnership with Japan and supports our strategy to expand our global LNG footprint,” said Rashid Khalfan Al Mazrouei, ADNOC Senior Vice President, Marketing.

“Through our world-class Ruwais LNG project, ADNOC will continue to provide more lowercarbon gas to meet growing global demand, fuel industries and power homes.”

Saad Sherida Al-Kaabi, Qatar’s Minister of State for Energy Affairs and President and CEO of QatarEnergy, held cooperation talks with senior executives of major Indian energy companies on the sidelines of the India Energy Week in New Delhi in February.

Al-Kaabi met separately with the top executives of Indian Oil Corporation, Gujarat State Petroleum Corporation Limited, Gujarat Gas Limited, and Petronet Energy. Discussions focused on existing and future cooperation, and on further strengthening bilateral relations in the energy sector, QatarEnergy said. 

“The Resource Accounts show high and stable production on the NCS, while resource growth from exploration was low in 2024,” said Nadine Mader-Kayser, Assistant director for Data and analysis in Technology, analysis and coexistence.

“If we are to maintain this production level in the years to come, we will have to increase exploration and investment in new projects.”

The Norwegian Offshore Directorate has also upgraded its FactMaps, making the service easier to use. The FactMaps have been migrated to a newer, more flexible technology. This provides some new functionality, such as the inclusion of third-party data from other players (UKCS/ENS). Predefined filters also make it easier to view data, the directorate said in February.

The authority has opened a consultation on a proposed new Regulation on data collection and documentation for mineral activities on the continental shelf. The deadline for comments is 30 April 2025.

Vår Energi has discovered oil in the Zagato prospect, directly north of the Goliat field in the Barents Sea, the Norwegian Offshore Directorate said at the end of February.

Wildcat well 7122/8-3 S was awarded in 1997 in a round of awards called the Barents Sea Project -97. The well was drilled by the COSL Prospector rig.

Preliminary estimates place the size of the discovery at between 15 and 43 million barrels of recoverable oil equivalent.

The licensees will assess the discovery together with other discoveries and prospects in the vicinity, with a view towards a potential development tied back to existing infrastructure on the Goliat field.

“2025 will be an exciting year for CO2 storage on the NCS,” commented Ann Helen Hansen, CCS coordinator in the Norwegian Offshore Directorate.

In 2024, more licences were granted for storing CO2 on the Norwegian continental shelf than ever before. Four exploration licences were granted in 2024, and offers were extended for two exploration licences.

Activity is expected to remain high in 2025, too, according to the directorate.

Safe and prudent storage of CO2 could become a new industry that can build on the experience we’ve gained from the oil and gas industry. There are environmental measures here that offer good earning opportunities for the companies

Vår Energi is active in the area surrounding Goliat and plans to conduct further exploration. The next scheduled well for the rig is 7122/7-8, “Goliat nord”.

CO2 Storage Offshore Norway Could Become New Industry

Northern Pioneer, a ship that will transport CO2 from customers in Norway and Europe to the CO2 receiving terminal in Øygarden, was christened in February, marking the beginning of what could become a new industry on the Norwegian shelf, the Norwegian Offshore Directorate said.

Several types of development solutions are being considered in the projects. These include onshore

facilities where ships transport CO2 to the facilities on land for interim storage and further transport via pipelines to the storage location, direct injection from ships, as well as pipelines from Europe.

“Safe and prudent storage of CO2 could become a new industry that can build on the experience we’ve gained from the oil and gas industry. There are environmental measures here that offer good earning opportunities for the companies,” says Hansen.

Norway Scraps Offshore Wind Tender, Focuses on Floating Wind

The Norwegian Energy Ministry said in February that it would not be holding a tender for the Sørvest F offshore wind area in 2025, due to high costs to connect power to the grid.

The decision not to tender Sørvest F follows a study by power system operator Statnett, which showed that costs would be high for grid connection regardless of the solution that the potential developers would have chosen.

Stattnet’s report assessed five grid concepts, one of which is radially connected to Norway, while the other four are various hybrid grid concepts where the offshore wind is also connected to one of Norway’s neighbouring countries.

“Costs are high, with significant variation in outcomes, for all grid concepts. This is due to the long distance to land, increased raw material prices and margins in the supplier market,” Stattnet said in the report commissioned by the Energy Ministry.

Instead of fixed-bottom offshore wind at Sørvest F, the Norwegian government will prioritise floating wind with radial links to the grid.

Norway currently faces high costs in both offshore wind production and the grid connection solutions, Energy Minister Terje Aasland said. Offshore wind production will depend on significant government support, regardless of which grid solution is chosen, Aasland added.

“I am sceptical of further exposing the Norwegian power system to the power challenges we have seen in Germany and other countries in Europe” recently, the minister noted.

Meanwhile, the government is working to announce areas for floating offshore wind as soon as possible. Floating offshore wind could be able to deliver power along the entire Norwegian coast, the government says.

Norway isn’t ditching offshore wind with hybrid grid solutions for good—it remains open to these if the cost levels and regulatory environment in Europe change. 

Australia Energy Review

By Tsvetana Paraskova

“As a trading nation, being competitive in global markets has long been essential to Australia’s economic success,” the executive added.

our disciplined approach and commitment to safety, reliability and performance,” CEO O’Neill said.

Oil and gas operators in Australia continue to increase production and approve new projects, but the country will need to do more to remain competitive with other major energy exporters at a time of rising trade frictions and protectionism.

“Affordable energy keeps operating costs down which means companies have more capital to invest in things that increase productivity,” O’Neill noted.

Australia needs a strong energy system with affordable energy costs to prosper and remain competitive on the global energy markets, said Woodside’s chief executive.

About 50 percent of the energy Woodside supplies domestically in Western Australia is used by mining customers to produce and process Australia’s resources. Therefore, investment in new natural gas supply could result in “the next wave of growth for an industry that is so important to Australia’s ongoing prosperity, by supporting the emergence of a critical minerals processing sector, and the decarbonisation of steelmaking,” O’Neill said.

In 2024, Woodside boasted a record annual production at the top end of the full-year guidance range, underpinned by consistently strong 98-percent reliability at its operated LNG facilities, the executive said in the fullyear results release.

Woodside’s major growth projects have progressed, with the Scarborough Energy Project now 80 percent complete and on track for first LNG cargo in 2026.

As a trading nation, being competitive in global markets has long been essential to Australia’s economic success

Last year Woodside signed three agreements for the long-term sale of LNG to customers in Japan, South Korea, and Taiwan in deals that “demonstrate the value that regional energy customers place on security and certainty of supply, and the ongoing role of LNG in balancing our customers’ energy security and decarbonisation needs,” the company said.

“Australia must sharpen its competitive edge”

Meg O’Neill, CEO and Managing Director of one of Australia’s top energy firms, Woodside Energy, said in a speech in February that “Amid rising global protectionism and greater competition for capital, Australia must sharpen its competitive edge even further.”

Australia faces a challenge in competing with the US, for example, where the new Administration has moved to deregulate the economy and spur new investments, O’Neill said in a speech to the Melbourne Mining Club.

The executive called on all levels of government to speed up approvals of new projects.

Higher Oil & Gas Production and Reserves and New Projects

Woodside reported in February that its proved reserves increased by 54.9 MMboe, while proved plus probable reserves increased by 46.2 MMboe, excluding divestments and production. Proved reserves life is now 9.6 years and proved plus probable reserves life is 15 years at 2024 production levels, the company said.

“As Woodside embarks on the next phase of growth, continuing to execute Scarborough and Trion and preparing for a final investment decision on Louisiana LNG, we will maintain

Another major firm, ExxonMobil, announced that its Australian subsidiary Esso Australia Resources Pty Ltd would invest $200 million in the Kipper 1B Project which will bring online much-needed additional gas supply from the Gippsland Basin offshore southeastern Australia.

The project includes the drilling and installation of one subsea well into the Kipper field, and significant upgrades to the West Tuna platform. Kipper 1B is expected to expand capacity from the Kipper field, delivering crucial gas supplies to the market ahead of winter 2026, Exxon said.

“Esso Australia continues to invest in multiple projects that ensure our Gippsland operations sustain gas production well into the 2030s,” says ExxonMobil Australia Chair Simon Younger.

“Natural gas is a safety net of our energy system, ensuring reliable, affordable power for homes and businesses while providing the stability needed to transition to a lower carbon future,” Younger added.

Santos, for its part, announced in February that first production from the Halyard-2 infill well had commenced. Santos, one of Western Australia’s largest domestic gas suppliers, said that the well is online six weeks ahead of schedule and is now producing.

The infill well is a valuable short-cycle capex project, delivering incremental low-cost volumes into the portfolio through to 2027, and supporting a reduction in unit production costs in 2025, Santos managing director and CEO Kevin Gallagher said.

Santos also updated the market on its Moomba Carbon Capture and Storage project (Moomba CCS) in South Australia’s Cooper Basin. The project, which started up in October 2024, at year end had already stored 340,000 tonnes of CO2-equivalent (CO2e).

Moomba CCS, Australia’s first large-scale onshore carbon capture and storage project, is storing CO2 in the same geological reservoirs that have held oil and gas in place for tens of millions of years.

At full injection rates Moomba CCS avoids more CO2 in four days than 10,000 electric vehicles save in one year, Santos said.

Australia’s Clean Energy Investment Reaches New Highs

In 2024, Australia saw its best year for largescale renewable energy investment since 2018, finishing the year strong with AUS$9 billion (US$5.6 billion) in total capital investment committed to projects, according to figures released by the Clean Energy Council.

Full-year 2024 turned out to be the best year for large-scale renewable energy investment since 2018, with 4,346 MW of new generation capacity committed. Additionally, 4,029MW / 11,348 MWh of new energy storage projects were also committed over the year.

The Quarterly Clean Energy Investment Report for Q4 found that seven new large scale renewable energy projects, representing 1,598 MW of new generation capacity and AUS$2.4 billion (US$1.5 billion) of capital investment were financially committed in the fourth quarter of 2024. The quarter also saw 870 MW / 1,936 MWh worth of storage projects reach financial commitment.

Clean Energy Council Chief Executive, Kane Thornton, said the strong quarterly result was in line with the pace required for Australia to hit its target of 82 percent renewables by 2030.

“Clean energy already powers around half of our national energy needs. We have now seen two consecutive quarters of very healthy investment activity in 2024,” Thornton said.

“Wind and solar combined with energy storage is the lowest cost form of electricity generation. We need more of these clean power stations in the system, together with gas in the interim, to reach our target of replacing unreliable and expensive coal power, before cheaper wholesale prices can start to flow through to peoples’ energy bills.”

Australia also looks to boost electrification of homes. Minister for Climate Change and Energy Chris Bowen has asked the Australian Renewable Energy Agency (ARENA) to consider funding for more community electrification demonstration projects across Australia.

The funding could help thousands of households electrify their home and save on energy bills with more rooftop solar, batteries, energy-efficient appliances, and shared community energy storage.

This is the first time that Minister Bowen has used the statutory ministerial referral powers to ask the ARENA board to look at backing specific projects.

Separately, EVX Australia will roll out EVcharging infrastructure across New South Wales, Victoria, and South Australia with AUS$2.4 million (US$1.5 million) funding from ARENA.

More than a third of drivers are thinking about getting an EV in the next 5 years, so the Australian Government is stepping up with more community EV chargers that use existing power poles, the federal government said.

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BOURDON OIL DISCOVERY

BW Energy has announced an oil discovery after drilling a well to a total depth of 4,135 metres using the Norve jack-up rig. While the company has not disclosed the estimated size of the find, initial analysis suggests the potential for establishing a new development cluster with a production facility, following MaBoMo. Additionally, a second well is being considered to further appraise the discovery.

CRONOS GAS FIELD

An agreement has been signed between the governments of Cyprus and Egypt to enable the project’s fast development. It will utilise Zohr field’s existing offshore facilities to transport and process the gas in Egypt, to be then liquefied in the Damietta LNG plant for export to European markets.

AUSTRALIA

KIPPER 1B PROJECT

ExxonMobil and its partners have taken the FID with an investment of $127 million for the Kipper 1B project. The aim of the project is to expand capacity from the Kipper field and exploit additional gas reserves from the Gippsland Basin. The Valaris jack-up rig, Valaris 107, will be deployed to drill and install one subsea well in the Kipper field. Simultaneously, the West Tuna platform will also undergo significant upgrades.

NETHERLANDS

PORT OF ROTTERDAM CO2 TRANSPORTATION & STORAGE PROJECT

Expro has been awarded a contract to supply tubular running services (TRS) for the project. The contract covers the recompletion and conversion of legacy offshore gas production wells into CO2 injection wells, decommissioning of shallow wells, and drilling of platform slot recovery wells. The company stated it will use its non-marking TRS technology, specifically designed to run corrosion-resistant alloy (CRA) tubular.

DEEPC STORE CCS HUB

DeepC Store has signed an agreement with TGS to carry out subsurface well location planning, storage resource verification and evaluation for carbon storage in the G-14-AP permit area. The work activities will be carried out throughout 2025. The development will be a floating offshore carbon dioxide capture and storage hub project in the Browse Basin, offshore Australia.

KUDU GAS FIELD

BW Energy has submitted Environmental and Social Impact Assessment (ESIA) documents for approval to drill up to four appraisal wells at the project site. The company intends to drill two wells in the first year and another two in the second year. Each well is expected to require approximately 70 days for drilling, followed by an additional 15 days for testing.

MISTRAL SØR GAS AND CONDENSATE DISCOVERY

Equinor has announced a gas and condensate discovery at Mistral Sør. The well was drilled by Odfjell Drilling’s Deepsea Atlantic semi-submersible rig, and preliminary estimates indicate the discovery containing between 19 and 44MMboe. The discovery was made in the Aasgard and Kristin area in the Norwegian Sea, a short distance north of Linnorm.

WEIZHOU 10-5 OIL AND GAS FIELD

CNOOC has made an oil and gas discovery at the Weizhou 10-5 field, located in the Beibu Gulf Basin. The WZ10-5-1Sa well was drilled to a total depth of 4,840 metres and encountered a 283-metre oil and gas pay zone. During initial testing, the well recorded a production rate of 13.2 MMcf/d of natural gas and 800 b/d of oil.

MOPANE OIL DISCOVERY

Galp has announced a new exploration discovery at Mopane-3X. Drilled by the drillship Santorini, the well is located 18 km from Mopane-1X and has confirmed the presence of light oil and gas-condensate with high pressures and permeabilities. The collected data will be analysed, and a 3D seismic acquisition campaign is scheduled for completion in Q1 2025, followed by processing of the new discovery’s information.

AZERBAIJAN

APSHERON FULL FIELD DEVELOPMENT –PHASE 2

The FEED works have commenced, with the target of reaching readiness for FID within a year. The project will likely be a four-well subsea development with an option for a fifth well if needed to achieve annual production of 6 Bcm/yr (211.9 Bcf/yr) of gas.

YELLOWTAIL OIL FIELD

EnerMech has been contracted by SBM Offshore to undertake pre-commissioning work on the One Guyana FPSO. The scope of the contract includes the execution of critical operations including offshore risers leak testing, gas injection riser de-watering, umbilical electrical and fibre optic testing, along with the installation of interconnecting tubing and flushing and testing equipment

PAPA-TERRA INFILL DRILLING PROGRAMME

Brava has announced the final investment decision (FID) for the Atlanta and Papa-Terra campaign, which includes drilling and connecting two new wells in Atlanta’s Definitive System and enhancing the recovery factor at Papa-Terra with two additional wells. Moreover, there is an option to develop Malombe by drilling a well and pursuing a tieback to Peroa. The total investment exceeds R$6bn (US$1bn), with operations set to begin in Q4 2025.

To address challenges, the regulator is developing a holistic well decommissioning programme for 2026-2030 reflecting the market capacity necessary to meet well decommissioning demand for that period, while also identifying credible campaigning and collaboration opportunities.

The NSTA is also holding industry to account on its decommissioning obligations, including well decommissioning, through its regulatory powers.

Regulator Investigates Well Decommissioning Delays

In line with the pledge to hold industry to account, the NSTA in 2024 opened investigations into missed deadlines for well decommissioning.

Members of the NSTA’s Directorate of Regulation have commenced investigations relating to alleged failures to complete timely plugging and abandonment in line with approved plans.

The regulator warned North Sea operators that they must take action on well decommissioning to support the UK’s supply chain, clean up their oil and gas legacy, and stop costs spiralling.

Continued delays to well plugging and abandonment (P&A) work, competition for rigs from overseas, and cost pressures are pushing up the estimated bill for decommissioning on the UK Continental Shelf, the NSTA said after it published its 2024 report on decommissioning costs and performance.

“Taking too long, or deferring work, adds to the cost and can mean that platforms continue to use power and release emissions even though they are no longer producing oil and gas,” the regulator says.

Decommissioning can ensure that the UK’s supply chain is equipped to help operators clean up their oil and gas infrastructure over the next 50 years and support the carbon storage sector, which will rely on many of the same resources, said Pauline Innes, the NSTA’s Supply Chain and Decommissioning Director.

“I am concerned that this huge opportunity to safeguard highly-skilled jobs and support the transition will be wasted if operators fail to tackle their well decommissioning backlogs,” Innes added.

“The supply chain wants to do this work, but it is not physically tied to the UK. Its skills and resources are in demand in other regions, and we are starting to see companies marketing their rigs elsewhere. Operators need to use the supply chain, now, or risk losing it.”

Supply Chain Opportunities for Homegrown Energy Transition

OEUK, the offshore energy industry body, also noted in its Offshore Decommissioning Report 2024 the crucial role that decommissioning plays in advancing the energy transition, showcasing innovative reuse and dismantling strategies alongside collaboration with offshore wind projects.

While the UK continues to build decommissioning capacity and capability, both sides of the market, the operators and the supply chain, need to collaborate more, Mark Wilson, HSE & Operations Director Offshore Energies UK, wrote in a foreword to the report published in November 2024.

Current uncertainty arising from the reforecasting of projects’ economics is chilling the decision making process, Wilson noted.

Decommissioning could also provide supply chain opportunities for a homegrown energy transition, OEUK’s report says.

“The operator and supply chain community are working more closely than ever and delivering groundbreaking project execution in all aspects of decommissioning,” the industry body notes.

However, OEUK warns that these results are overshadowed by the economic and fiscal uncertainty and macroeconomic factors including inflation.

“Without a stable fiscal regime, investment will dry up and the workflow will stagnate. The workforce has been promised a just energy transition. There is no energy transition without a healthy UK supply chain and there is no UK supply chain without investment,” OEUK said. “Challenges on Several Fronts”

The North Sea decommissioning industry faces challenges on several fronts, Wood Mackenzie said in a December report.

The energy consultancy estimates gross decommissioning costs are expected to eclipse development capex by 2032 and peak at over US$3.5 billion per year in the mid-2030s.

While the UK Government’s Energy Profits Levy (EPL) has accelerated decommissioning for several assets, WoodMac’s latest analysis found that a series of technical, logistical, legal, regulatory, commercial, and financial complexities will likely lead to continued delayed decommissioning on the UKCS.

“The growth of small players has been key to rejuvenating old assets, but decommissioning, and the potential acceleration of it, presents increasing risks to JV partners and the UK government which presents companies with more reason to keep kicking the decommissioning can down the road,” said James Reid, Senior Research Analyst at Wood Mackenzie. 

By Tsvetana Paraskova

J+S Subsea Expands Globally: Unlocking Subsea Potential in Australia

With fresh investment backing their international expansion, the company is poised to offer its renowned expertise to a region showing strong signs of interest in its capabilities.

We have teamed up with experienced Business Development Manager Thomas Hutchinson, who has recently re-joined the J+S Subsea team to lead this expansion. He brings a wealth of experience to the role, having previously contributed to the company’s success and now returning to drive its international growth. Thomas will be responsible for strengthening relationships with key stakeholders and identifying opportunities to support operators in Australia’s growing subsea sector. His

J+S Subsea, the award-winning subsea controls specialist known for delivering innovative and sustainable solutions, is set to make a significant impact on the Australian market.

mission is clear: position J+S Subsea as a trusted partner for subsea controls and latelife asset management.

One of the core elements of J+S Subsea’s entry into the Australian market will be its flagship initiative, the Legacy Locker. The Legacy Locker addresses equipment obsolescence through a circular economy approach—remanufacturing, recertifying and reusing existing subsea assets to minimise lead times and support sustainability goals. The programme is expected to be a vital solution for Australian operators seeking to extend the life of ageing subsea infrastructure while keeping operations efficient and environmentally sound.

“We’ve already seen signs of interest from operators in Australia who are eager to explore our innovative solutions,” said Thomas. “The Legacy Locker is perfectly suited to address late-life asset challenges, and we’re confident that our reactive and tailored approach will resonate well with the market.”

J+S Subsea’s reputation for being highly responsive and adaptive to the needs of their clients has earned them numerous accolades, including recent recognition for innovation in the supply chain. Their ability to provide customised, cost-effective solutions— whether through refurbishing existing equipment, delivering critical components or designing bespoke systems—is expected to give them a competitive edge in Australia.

As the subsea sector in the region grows, J+S Subsea’s proactive approach aims to support operators with practical, reliable and sustainable solutions. With strong backing, experienced leadership and innovative offerings, J+S Subsea is set to establish itself as a key player in Australia’s evolving subsea landscape. 

Zenith Energy: Leading The Way In Well Decommissioning

Decommissioning is at the heart of what we do at Zenith Energy. Since our inception, we have been actively involved in well decommissioning projects worldwide, providing end-to-end solutions that ensure safe, efficient, and costeffective well abandonment. Over the past few years, a significant amount of our projects have been decommissioning related, solidifying our reputation as a trusted partner in the industry.

ESTABLISHING A LEGACY IN DECOMMISSIONING

Recognising the evolving needs of the oil and gas sector, we strategically positioned ourselves as a leader in well plug and abandonment (P&A) workscopes. This foresight led to significant contract wins, including our first major P&A project in 2014— abandonment planning for nine subsea development and water injection wells offshore Ivory Coast. Since then, we have successfully delivered over 25 decommissioning projects for 15 clients across the UK, Australia, Europe, and Africa. Our track record spans a diverse range of environments, including onshore, offshore, rig-less, deepwater, high-pressure hightemperature (HPHT) wells, high H₂S conditions, and Carbon Capture, Utilisation, and Storage (CCUS) projects.

CUTTING-EDGE

PROJECTS

& INDUSTRY COLLABORATION

We are currently engaged in a groundbreaking project with key industry stakeholders, conducting a detailed analysis of historical UKCS P&A operations. Our work involves generating time and cost estimates for over 1,500 wells scheduled for decommissioning, assessing rig suitability, and forecasting supply chain requirements. This project is set to provide invaluable insights that will shape future decommissioning strategies across the sector.

UNMATCHED EXPERTISE & INNOVATION

Our personnel bring over 40 years of global well abandonment experience, supported by an extensive lessons-learned database that drives continuous improvement. Central to our approach is the Zenith Well Abandonment Delivery Process, a framework refined over years of hands-on experience to ensure consistency and excellence across all operations.

WHY CHOOSE ZENITH ENERGY?

Independent & Engineer-Owned: Our company understands the complexities of well decommissioning from an operational perspective, enabling swift, informed decision-making.

Adaptability & Strategic Partnerships: Whether working on short-term studies or long-term campaigns, we collaborate with industry stakeholders to deliver fit-for-purpose solutions within a commercial model that suits our clients.

Proven Track Record: Our expertise spans multiple operators, countries and well types. Operators we have worked for include CNOOC, Repsol, ENI, CNRL, and Mitsui, where we have proven our ability to execute projects of varying complexities.

At Zenith Energy, we don’t just follow industry best practices—we help define them. As decommissioning continues to shape the future of the energy sector, we remain at the forefront, delivering safe, sustainable, and innovative solutions to our clients worldwide.

For more information on our well decommissioning services, visit zenith-energy.com/our-services/ well-decommissioning

ZENITH DECOM

P&A

Integrated Subsurface and Wells Basis of Design: A role vital to effective and efficient decommissioning

By Derek Littlejohn, Subsurface Decommissioning Manager, Elemental Energies

Early engagement and collaboration between wells and subsurface teams allow other critical areas of decommissioning to be mapped correctly, helping to drive efficiency across the entirety of a decommissioning programme.

NSTA Expectations

The NSTA is holding the industry accountable for its decommissioning obligations and is driving a holistic well decommissioning programme for 2026-2030, when multiple operators are expected to enter the market. By increasing visibility of planned scopes and stewarding licensees, the NSTA aims to ensure supply chain capacity while enabling efficient, collaborative, and safe decommissioning.

This obligation is best met by assessing an asset or hub’s late-life operations through a structured glidepath well before Cessation of Production (CoP), as shown in NSTA’s Glidepath for Success (Fig. 1 below). A key step in this process is understanding the subsurface and wells inventory and history—crucial for estimating P&A programme duration, identifying the need for innovation, engaging regulators, and determining where deviations from the base plan may be required.

P&A Cost and Performance

Decommissioning performance metrics introduced in 2023 show that the three primary categories – development wells, topside removals, and substructure removals – are all falling short of planned attainment. The industry is under increasing pressure to deliver on forecasted plans, with increasing cost bases being a key factor in delays.

Well P&A accounts for approximately 50-60% of the total decommissioning cost within any given hub, and this cost is expected to increase further due to inflationary pressures. The total forecasted decommissioning cost in the UKCS through 2032 is expected to exceed £10 billion.

When tackling the decommissioning of an asset or asset hub, it is crucial to establish a common understanding of the risks and opportunities associated with both wells and the subsurface as early as possible in the planning process.

With decommissioning plans falling behind schedule and the number of inactive wells rising year on year, it is vital to mitigate additional costs and uncertainties caused by inadequate planning. This is where a fully integrated subsurface and wells basis of design process becomes essential.

Planning and the Importance of the Basis of Design

All elements of the NSTA’s Glidepath to Success are influenced by subsurface and wells basis of designs. Across the full decommissioning effort, collaboration and expertise in these areas are essential for developing the subsurface basis of design and well abandonment design—both fundamental to delivering a safe and costeffective P&A programme.

Early engagement in this process provides the time and insights needed to capitalise on opportunities – whether through developing new technologies, challenging standards, or simply ensuring that the asset has the necessary information to plan the most efficient and cost-effective decommissioning programme possible.

Elemental Energies' Philosophy

Elemental Energies recognises these challenges and the need for early, effective engagement through an integrated, full-field approach. This approach encompasses everything from field repurposing and legacy well integrity to commercial and contractual considerations, drawing on expertise from geophysics to well engineering. By driving tangible cost savings and operational efficiencies throughout decommissioning, this methodology ensures a streamlined process. With experience across 25+ fields and over a decade of supply chain and operator decommissioning expertise, Elemental Energies’ subsurface and wells professionals are well positioned to support the industry’s decommissioning obligations.

Cross-Industry Collaboration

Integration extends beyond wells and subsurface teams. Across the UKCS, operators and supply chain companies are actively collaborating, regularly sharing knowledge and experiences to enhance overall industry performance.

Subsurface and wells teams are crucial to this effort, playing a vital role in delivering a holistic, efficient, and cost-effective decommissioning effort in the UKCS. 

NSTA

NSTA

Delivering

Safe and Cost-Effective Decommissioning…

the THREE60 Energy Way

In the rapidly evolving landscape of the energy industry, decommissioning has emerged as a critical focus area. As assets reach the end of their productive life, the need for safe and cost-effective decommissioning solutions becomes paramount.

THREE60 has positioned itself as a leader in this domain, offering a suite of services that stand out for their novel approach and proven delivery track record.

Decommissioning is a complex and multifaceted process that involves the safe dismantling and removal of offshore and onshore production infrastructure. This includes everything from wells and pipelines to topsides and substructures. The goal is to minimise environmental impact, ensure safety, and comply with regulatory requirements while managing costs effectively. THREE60 has developed robust decommissioning delivery models that address these challenges head-on, leveraging its extensive capability, experience and innovative solutions.

The company's menu-driven approach allows clients to select from a range of services tailored to their specific needs. Whether it's a standalone study, engineering services, or a full-scale decommissioning project from subsurface and wells to pipelines and infrastructure removal, THREE60 can provide the necessary expertise. This flexibility is crucial in an industry where project requirements can vary significantly. This approach has been particularly successful for THREE60 in offering cost-effective solutions without compromising on quality or safety.

THREE60 provide pragmatic decommissioning solutions that are tailored to each individual clients requirements.

THREE60’s offers a comprehensive range of decommissioning services with increasing value to their customers:

• Discreet Consulting: Includes independent reviews, assurance and readiness assessments, due diligence, and abandonment expenditure benchmarking (ABEX).

• Solution Partner: Access to skilled nominated personnel, computerized maintenance management system assessments, late life and Cessation of Production (CoP) strategy development, acquisition & divestment support, preoperations services, and maintenance and integrity builds.

• Operations & Maintenance (O&M): Services encompass commissioning execution, operations & maintenance delivery, campaign management, engineering, down & clean execution, and production loss analysis.

• Integrated Services Provider (ISP): Technical authority services along with logistics management, asset integrity delivery, and transition management.

• Asset Management: Acts as a duty holder while managing late life operations including well operations and decommissioning management.

The industry is increasingly recognising the complexities in maintaining operationsoriented teams for decommissioning projects. By outsourcing all or part of these projects to specialist companies with a breadth of capabilities and a relevant mindset, operators can significantly reduce costs

and streamline processes. THREE60’s fully outsourced model is exemplified by their work with a major North Sea operator, where they are challenging traditional operating structures, leading to the realisation of significant efficiencies throughout the entire lifecycle of the project. THREE60 have a proactive approach to decommissioning and on a recent project started preparations prior to CoP, ensuring the assets readiness for efficient decommissioning.

Amongst the variety of models THREE60 offers is the Integrated Service Provider (ISP) model, which bundles various discrete services into a cohesive package. This approach simplifies management, reduces interfaces, and enhances efficiency. As an example, in 2023 THREE60 assumed responsibility for a platform in the Northern North Sea, where they combined engineering and O&M under one ISP, demonstrating the effectiveness of this model. This integration ensures a seamless transition from late-life operations to decommissioning.

Safety and cost certainty are at the core of THREE60's decommissioning delivery. The business and its people have a strong track record of executing projects within budget, a critical factor given the historic unpredictable nature of decommissioning projects. Many projects have exceeded their budgeted costs. THREE60's deep understanding, meticulous planning and execution excellence help to mitigate this risk. Additionally, their unwavering commitment to safety ensures that all projects are executed without compromising the well-being of personnel and the environment.

The decommissioning landscape is now evolving after years of industry consultation, with significant financial implications for the oil and gas industry. According to the Offshore Energies UK (OEUK) Decommissioning Insight Report, decommissioning expenditure in the UK Continental Shelf (UKCS) is expected to account for 33% of total oil and gas expenditure by 2030, surpassing capital investment. This shift underscores the growing importance of innovative decommissioning solutions.

Furthermore, the North Sea Transition Authority (NSTA) has reported that the cost of decommissioning projects has often exceeded initial estimates. In 2023 it was estimated that operators were expected

to spend £21bn on decommissioning between 2023 - 2032, however, in the same report issued in 2024 the estimate had grown to £24bn for the same period, further highlighting the need for forward-thinking and reliable service providers like THREE60. The company's ability to deliver projects within budget is a significant advantage in this context.

THREE60's ongoing work in the North Sea highlights its ability to deliver decommissioning solutions, in an era where the cost is currently increasing. By outsourcing the decommissioning of the assets to THREE60, operators are able to reduce their overheads and transition to a lightweight operating model allowing them to focus on core operations.

THREE60's decommissioning offerings are characterised by their comprehensive outsourcing models, including as integrated services provider, their menu-driven approach, and their focus on cost certainty and safety. These differentiators, combined with their proven track record and industry expertise, make them a preferred partner for oil and gas operators looking to navigate the complex decommissioning landscape. As the industry continues to evolve, THREE60's innovative tailored solutions and commitment to excellence positions them at the forefront of the decommissioning sector.

Case Study:

The Schooner & Ketch fields in the Southern North Sea (SNS), operated by DNO, presented a unique challenge due to their normally unmanned status and campaign-based maintenance by intervention teams. Seeking a flexible, low-cost decommissioning solution, DNO appointed THREE60 to provide comprehensive Duty Holder O&M services, along with integrity, engineering, procurement, construction, and decommissioning support activities. This service was delivered by THREE60's onshore team in Aberdeen, supported by their engineering team and virtual Technical Advisory Network, encompassing all management systems and emergency response. The result was a successful transition and a cost reduction of approximately 30% allowing plug & abandonment and removal scopes to commence. The decommissioning scope for this project was completed in May 2023. 

decontamination and segregation, Sureclean offers adaptable engineered solutions tailored to client needs and turnaround times.

This approach is already delivering results for major UKCS operators, interest from international operators, and seen as a step change by regulators.

Sureclean CEO Simon Gibb is passionate about the benefits of carrying out NORM decontamination earlier in the decommissioning process: “There is a misconception that offshore NORM removal is more complex, but in reality, it is safer and more cost-effective, with a demonstrable time saving in the long term. Offshore NORM decontamination is the strategic, compliant, risk-reducing approach to timely and effective decommissioning.

“By embedding NORM decontamination within a modular, scalable industrial cleaning framework, organisations can double operational efficiency while halving environmental impact. For us, decommissioning isn’t just about cleaning up the past; it’s a sure thing for shaping a sustainable future.”

International Success

Sureclean’s commitment to sustainability extends globally. Supported by in-house RPA/RWA expertise, the team provides international NORM decontamination solutions, including temporary site setups, equipment mobilisation, and regulatory guidance. A successful prototype in Angola demonstrated the global applicability of the Sureclean model.

A fully functioning, temporary decontamination facility was established using UHP jetting, bunded containment, and advanced water treatment—preserving natural resources while minimising waste.

As the global energy industry navigates the complexities of decommissioning, adopting sustainable, performance-led NORM decontamination practices is proving to be a strategic advantage. From offshore interventions that save time and reduce risk at the source to scalable onshore solutions that prioritise environmental responsibility, this approach redefines effective decommissioning. With safety, compliance, and time-saving at its core, the future of NORM management is not just about meeting regulations—it's about raising the sustainability bar.

“Offshore NORM decontamination is the strategic, compliant, timesaving and risk-reducing approach to effective decommissioning.”

Simon Gibb – CEO, Sureclean

Drilling into decommissioning –stimulating the stagnant market

Laura Petrie, partner and Katie Millar, associate, Brodies LLP

It’s fair to say that recent months have been tough on the oil and gas industry. Windfall tax, judicial reviews and international focus pulling resources away from the UK has all meant that the North Sea has experienced a significant slow down in activity.

This is especially true in respect of decommissioning scopes. As operators seek to minimise costs, manage their stewardship and 'maximising economic recovery' obligations and focus on simply keeping the lights on (both for the UK as a whole but also commercially in some cases) the need to carry out plugging and abandonment or wider decommissioning work is falling lower down the priority list.

But what really is the state of the decommissioning industry in the UKCS at present and how can operators and supply chain best work together to stimulate what appears to be a stagnant market?

Drilling into the details of decom

The Offshore Energies UK (OEUK) Offshore Decommissioning Report 2024 was published on 1 November 2024 and identified that while decommissioning spend in the United Kingdom Continental Shelf (UKCS) had increased throughout 2024 in comparison to 2023, "considerably less work was completed compared with the forecast" and "the basin will require a step change in activities to realise the forecast".

This begs the following questions –

1. What has caused this stagnation; and 2. What is the key to unlocking and facilitating progress?

In terms of the first question, the main factors appear to be high and increasing costs teamed with small individual projects, and a lack of exclusivity for the supply chain. This is something that the North Sea Transition Authority's (NSTA) had already been taking steps to try to address via its Decommissioning Data Visibility project that piloted in 2021 and was expanded upon in February 2024. The idea being that the availability of data relating to upcoming decommissioning projects would allow the service sector to allocate resources and skills with the confidence that they will be utilised, while also allowing operators the ability to identify potential opportunities to establish decommissioning campaigns rather than commencing smaller (cost inefficient) individual projects.

It must be borne in mind that cost effective decommissioning forms Stewardship Expectation 10, and thus is something that all operators must be mindful of. In addition, NSTA's Decommissioning Strategy published in May 2021 pays particular attention to decommissioning at scale and identifies that data supplied via the UKCS Stewardship Survey can be used to identify opportunities to coordinate decommissioning activity.

Decommissioning supply and demand

There are different issues facing the service sector and this of course has a significant impact on the availability of resources and skills, and the associated costs. As it stands, many domestic service providers are opting to enter into contracts overseas rather than in the UKCS for a number of reasons, including a lack of clarity and transparency in respect of project timelines and costs.

In order to bring the supply chain's focus back to the UKCS and decommissioning work in particular there needs to be guaranteed work, with significant scopes and clear timelines.

This being the case, campaign work appears to be at least part of the answer to getting the market moving again. But what needs to be done to facilitate discussions and encourage operators and the supply chain to have meaningful engagements?

OEUK is currently working with industry to build a framework for alliance contracting which should help encourage operators and the supply chain to consider campaign work in the UKCS. These collaborative engagements underpin other areas of the oil and gas supply chain so it makes sense that they would be beneficial for decommissioning and as they offer cost-effective benefits to operators and engaged workscopes at value for the supply chain it should be a win-win situation.

As with many areas in energy, it is the role of those actively involved in the industry to work together to resolve the current stagnation in the decommissioning market. Industry bodies are helping to provide the keys to unlock workscopes but it falls to the operators and supply chain to turn those keys and get the maret moving. 

The UK’s largest innovation funding consultancy

Leyton is an international consulting firm that helps businesses leverage financial non-dilutive incentives to accelerate their growth and achieve long lasting performance.

We simplify your access to these complex incentives. Our combined teams of highly skilled Tax and Technical specialists, enhanced with cutting-edge digital tools developed internally, maximise the financial benefits for any type of business.

These end-of-life assets require careful management to ensure safe, compliant, cost-effective abandonment. Recent technological innovations are revolutionising this traditionally high-risk process.

Digital twin technology represents a breakthrough in decommissioning planning.

Solutions like AS-TEG™ create detailed 3D intelligence models of offshore platforms, allowing engineers to make precise decisions throughout the decommissioning process. This technology significantly reduces the need for dangerous in-person site surveys of ageing infrastructure. The innovative Engineer Down Clean (EDC) tool enables remote system "line walks" before cutting and removal activities, minimising personnel requirements during hazardous decommissioning phases.

IoT monitoring systems have evolved beyond operational oversight to address decommissioning-specific challenges. HiberHilo, initially designed for production monitoring, has been adapted to support wells transitioning into decommissioning. This solution is particularly valuable for isolated assets that would otherwise require expensive and potentially hazardous personnel visits for inspection.

Digital Technology Transforms Safety in Oil Well Decommissioning

Decommissioning

oil wells presents significant challenges, particularly for ageing infrastructure in remote locations.

Digital frameworks designed for plug and abandonment operations have emerged as critical safety tools. "PlugDigitize," a comprehensive digital framework, optimises cement plug placement during permanent well abandonment. This solution enhances operational procedures, reduces costs, and significantly improves safety in well abandonment activities—a crucial phase in proper decommissioning.

Regulatory compliance drives much innovation in this space. The "Well Abandon Alert" project, developed for monitoring subsea wells during temporary abandonment, aligns with regulatory requirements while employing advanced acoustic communication technologies. These digital solutions not only streamline compliance documentation but also enhance environmental protection through more precise monitoring of potential leakage points and improved verification of well integrity. This ensures adherence to standards such as ISO 27001 or NIST 800-88 Rev 1 throughout the decommissioning process while minimising environmental impact.

These technological innovations qualify for significant R&D tax incentives. The Research and Experimentation Tax Credit has been

expanded and made permanent, providing vital financial support for companies developing new or improved decommissioning processes. Qualifying activities include developing environmentally friendly technologies and enhancing safety methods during the abandonment process—precisely the innovations transforming the industry.

HMRC's R&D Tax Relief Scheme offers substantial benefits for companies engaged in decommissioning innovation. As a specialist in innovation funding, Leyton provides expert guidance for firms seeking financial backing for their decommissioning R&D endeavours. Our extensive experience helps companies secure significant tax relief for pioneering work that improves safety, efficiency, and environmental outcomes in this critical phase of the asset lifecycle.

As the industry continues to decommission ageing infrastructure at an accelerating pace, these digital innovations will be crucial for balancing safety, compliance, and cost considerations. By embracing these technologies and leveraging available tax incentives, operators can transform what was once seen as a liability into an opportunity for innovation and industry advancement. 

Benson John MSc CEng MIMeche (Assistant Manager - R&D

Equinor lets contract for Johan Sverdrup expansion

Equinor let a contract to Technip FMC for Johan Sverdrup Phase 3 development in the Norwegian North Sea.

Equinor Energy AS has let an integrated engineering, procurement, construction, and installation contract to Technip FMC for Johan Sverdrup Phase 3 development in the Norwegian North Sea.

Phase 3 development is expected to increase production by tying in additional wells to the current infrastructure.

The award, valued by Technip FMC between $500 million and $1 billion, follows an integrated front end engineering and design study.

TechnipFMC will design, manufacture, and install subsea production systems, umbilicals, and rigid pipe that will tie new templates into the existing Johan Sverdrup field center.

Johan Sverdrup details

Johan Sverdrup, which accounts for about one third of Norwegian oil production, lies on the Utsira High (Utsirahøyden) in the central part of the North Sea, 65 km northeast of Sleipner fields in water depth of 115 m.

Production from Phase 1 began in 2019. Production from Phase 2 started in 2022. The oil handling capacity was increased after a capacity test in 2023 confirmed the field can produce up to 755,000 b/d of oil.

The main reservoir contains oil in Upper Jurassic intra-Draupne sandstone. The reservoir depth is 1,900 m. The quality of the main reservoir is excellent with very high permeability. The remaining oil resources are in sandstone in the Upper Triassic Statfjord Group and Middle to Upper Jurassic Vestland Group, as well as in spiculites in the Upper Jurassic Viking Group. Oil was also proven in Permian Zechstein carbonates.

Equinor is operator of the field with 42.6267% interest. Partners are Aker BP (31.5733%), Petoro AS (17.36%), and TotalEnergies EP Norge AS (8.44%). 

Noble’s 2013-built rig picks up drilling gig offshore Suriname

U.S. offshore drilling contractor Noble Corporation has disclosed a new drilling assignment off the coast of Suriname for one of its jack-up rigs that reportedly wrapped up its assignment with France’s TotalEnergies in Argentina last month.

The Noble Regina Allen rig’s new one-well contract has been secured with an undisclosed operator offshore Suriname. The assignment is expected to span approximately 65 days, beginning in the fourth quarter of 2025. This deal will bring Noble a total value estimated at $17.7 million, including mobilization and demobilization fees.

Following a mechanical failure with the jacking system on one of its legs, the rig was demobilized to a port in Trinidad in 2022. The jack-up’s multi-well contract was terminated because of extended downtime, thus, it was off day rates since mid-December 2022. The rig underwent repair work in Rotterdam, the Netherlands.

The Noble Regina Allen jack-up rig was hired in September 2023 by TotalEnergies for a three-well contract in Argentina. The unit’s job was estimated to take 220 days, plus four one-well options. The jack-up arrived in the country last year to continue drilling gas wells at the Fénix platform.

TotalEnergies started production from its Fenix field in southern Argentina last year, but the contract for Noble’s jack-up was scheduled to begin in mid-2024 and end in February 2025. The deal came with an operating day rate of $150,000, excluding additional fees for mobilization and demobilization.

The 2013-built Noble Regina Allen jack-up rig is of Friede & Goldman JU3000N design. Constructed at Jurong Shipyard, the unit can accommodate 150 people. With a drilling depth capability of 35,000 feet (10.67 kilometers), this rig can operate in water depths of up to 400 feet (around 122 meters). 

Sapura Energy Secures $716.7MM of Drilling Contracts

Sapura Energy Berhad subsidiary Sapura Drilling said it has secured multiple contracts with a combined value of approximately $716.7 million (MYR 3.2 billion), including an optional period.

Sapura Drilling won two contracts from PTTEP Energy Development Limited for the provision of its tender assist drilling rigs, Sapura T-17 and Sapura T-18.

Both projects will begin in the second quarter of 2026, with a five-year firm period and an optional extension of three years, the Malaysian company said in a news release.

The company has also secured a contract extension from Chevron subsidiary Cabinda Gulf Oil Company Limited (CABGOC) for the tender assist drilling rig Sapura Jaya. The extension, which started in November 2024, will continue until November 2025.

Further, Sapura Drilling won a contract from ExxonMobil Exploration and Production Malaysia Inc. (EMEPMI) for services of the Sapura Berani drilling rig. The project, starting in the first quarter of 2026, involves development drilling for a period of 30 months.

Another contract was secured by the company from EnQuest Petroleum Production Malaysia Ltd for services by the Sapura Esperanza rig for drilling activities. The contract begins in the first quarter of 2026 and covers the drilling of four development wells offshore Malaysia.

Sapura Drilling has a fleet of five semi-tender rigs and six tender barge rigs, making it the largest drilling contractor in Southeast Asia by rig count and market share, it said.

The signed contracts have strengthened the group’s order book to a total value of $1.95 billion (MYR 8.7 billion) while the order book held by its joint ventures stood at $1.28 million (MYR 5.7 billion), the company said.

In addition to the drilling contracts, Sapura Energy’s Engineering and Construction segment has secured several key projects, including a pipeline installation in Brazil and an asset removal project in Australia.

Sapura Energy’s CEO for its drilling business, Louay Louis Laham, said, “Our strength lies in our people, our capabilities, and our partnerships. We not only focus on safety and operational excellence but also on our commitment to collaboration with our clients. That’s how we maintained a consistent track record with top tier clients for more than 50 years of existence”.

“These contract wins reflect our ability to deliver value-driven solutions and strengthen client confidence in Sapura Energy. As we grow our order book, we remain committed to operational excellence and long-term value creation”, said Muhammad Zamri Jusoh, Group CEO of Sapura Energy.

In December 2024, Sapura subsidiary Sapura Upstream Assets Sdn Bhd (SUA) completed the sale of its 50 percent equity interest in SapuraOMV Upstream Sdn Bhd to TotalEnergy Holdings SAS.

SapuraOMV’s assets include a 40 percent operated interest in block SK408 and a 30 percent operated interest in block SK310, both situated offshore Sarawak, Malaysia. The Jerun gas field, located within the SK408 block, achieved its first gas in July 2024, ahead of schedule and within budget. SapuraOMV also holds exploration licenses across strategic regions, including Malaysia, Australia, New Zealand, and Mexico, according to an earlier news release.

“This strategic initiative underscores our commitment to Sapura Energy’s long-term Reset and debt restructuring plan; this divestment streamlines our portfolio and enables us to focus on our core capabilities, namely to deliver safe and innovative solutions to the energy industry,” Sapura Energy Interim Chairman Shahin Farouque Jammal Ahmad said.

Odfjell Technology bags another deal with ConocoPhillips

Odfjell Technology, a spinoff of Odfjell Drilling that specialises in offshore operations, well-service technology, and engineering solutions, has won a threeyear deal with ConocoPhillips for work on the Norwegian Continental Shelf.

The new contract for tubular running services comes less than a month after the two companies agreed to extend a contract for platform drilling operation and maintenance services in the Norwegian North Sea.

The previously agreed extension will last until July 1, 2028, and also has another threeyear extension option which could see the partnership extend until July 2031.

According to Odfjell Technology, the new TRS deal has a firm duration of three years with two extension options of three years each.

“The new contract will provide continuity and predictability for both parties, underscoring their shared commitment to quality, safety, and efficiency in every aspect of their operations,” the Norwegian firm said. 

Ventus Energy wins two major contracts with Ocean Winds

Ventus Energy, a leading provider of high-voltage (HV) services, has secured two significant contracts with Ocean Winds to support its Scotland-based wind farms, Moray West and Moray East.

Both scopes will incorporate Elecsys, an advanced electricity network management system. Following a recent seven-figure investment developing its cutting edge software, Elecsys addresses unique challenges within networks by offering scalable digital solutions to support real-time operations, electrical safety coordination, and asset management. 

The Gyda Project Successfully Completed

The Gyda decommissioning and recycling project has officially ended, marking a significant milestone in sustainable offshore decommissioning. Over the course of the project, 28,000 tonnes of material have been dismantled with an impressive recycling rate of 98.5 per cent.

Offshore structures such as Gyda consist of large quantities of valuable materials that are in high demand on the world market, both as there is a need for more construction materials, but also because the production of reused steel, copper and aluminum emits far less CO2 than the production of new materials, said Bengt Hildisch, SVP Decommissioning in Aker Solutions.

The Repsol operated Gyda field was shut down in the autumn of 2021. Both jacket and topside were delivered to Stord by Allseas’ Pioneering Spirit in the summer of 2022. At delivery, the total weight of the platform and substructure was around 28,000 tonnes.

Safe and efficient dismantling

Recycling an offshore giant like Gyda is meticulous work. The transportation itself was spectacular. Pioneering Spirit, the world’s largest construction vessel and the vessel with the highest lifting capacity in the world, is one of the very few capable of handling such a task. Once the topside was safely skidded onto the dismantling pad, a comprehensive effort started to safely remove all hazardous waste, salvage reusable equipment, and clean the topside, before removing the large flare and derrick.

To ensure safe and productive deconstruction of Gyda, the Aker Solutions decommissioning team developed a machine-based method to dismantle the Gyda platform. By bringing section after section of the large platform down to the ground and within reach of the

heavy-duty cutting equipment, they ensured an efficient and controlled demolition process.

Johan Fredriksson described the process: “We peeled the platform layer by layer, ensuring a safe and controlled dismantling. Placing structures on the ground is a key part of Aker Solutions’ machine-based method, enabling safe and efficient dismantling. The HSSE benefit lies in reducing manual labor and minimizing work at height.”

Twelve toppling operations were executed on Gyda. The largest, on October 19, 2023, sent the 18,000-tonne topside to the ground. Approximately 50 kg of explosives were used, distributed across 28 charges placed on the legs and diagonal braces.

“These are complicated operations, that require extremely careful and precise engineering and planning activities. In many cases, dismantling structures is far more difficult than constructing them. I am impressed with the team at Stord and pleased that we managed to complete the project with good HSSE results,” said Hildisch.

A major contribution to sustainability

The completion of the Gyda project underscores Aker Solutions’ commitment to sustainability and circular economy principles. Recycled steel from Gyda has resulted in 40,758 tonnes less CO2 emissions compared to producing new steel, highlighting the crucial role of recycling in reducing industrial carbon footprints. 

Elemental Energies appoints Ross Provan as Head of Decommissioning Solutions

Elemental Energies is pleased to announce the senior management appointment of Ross Provan as Head of Decommissioning Solutions. Ross brings 18 years of projects and operational experience working with major global operators and contractors, with expertise spanning drilling, facilities engineering, subsea, project assurance, construction and decommissioning.

Elemental Energies has built a global reputation in engineering and project management, with specialist teams across subsurface, wells and facilities. The company has an extensive track record managing large scale platform plugging and abandonment (P&A), major subsea well decommissioning and integrated wells and facilities projects. Following a number of strategic acquisitions in the UK and Norway, and its recent joint venture announcement with Archer for global P&A, it continues to expand its technical expertise and service offering.

In his new role, Ross will lead Elemental Energies’ focus on EPRD (engineering, preparation, removal and disposal) and the integration of services, including the existing wells decommissioning capabilities, across all areas of the decommissioning work breakdown structure (WBS).

Mike Adams, CEO of Elemental Energies, commented:

“With global offshore decommissioning spend projected to double over the next two decades, the need for integrated, cost-effective and innovative solutions is crucial. We believe this approach to decommissioning presents significant opportunities for efficiencies, particularly when technical teams collaborate early in the process. We have seen these benefits firsthand through our successful delivery of integrated wells and facilities scopes. With Ross leading this key area, we are confident that his experience and expertise will help us to continue to drive innovation and efficiency in the decommissioning sector.” 

UPCOMING GLOBAL EVENTS

Middle East Energy Dubai

7-9 April 2025

Dubai, UAE

Expo Gas

8-10 April 2025

Kielce, Poland

International Green Energy Expo

23-25 Apr 2025

Daegu, South Korea

Oman Petroleum & Energy Show

12-14 May 2025

Muscat Oman

Africa Energies Summit

13-15 May 2025

London, United Kingdom

D&A AUS 2025

10-11 Jun 2025

The Crown Perth, Australia

SPE Offshore Europe

2-5 September 2025

Aberdeen, United Kingdom

Embrace the Future of Crew Travel Management

Jenny Thornton, Director of Technology Solutions

Across the energy sector, regardless of industry or individual role, managing corporate travel has traditionally been a complex undertaking.

From initial research to distributing eTickets for efficient crew changes and group bookings, HR and admin managers often need to set aside hours on burdensome and time-intensive travel-related tasks.

With energy operations taking crews to remote, offshore, and far-reaching destinations, the challenges of these tasks are only exacerbated. To effectively navigate them, companies need a holistic travel management solution that prioritises efficiency, safety, and cost control.

Key challenges in energy travel:

 Remote and Offshore Locations: Crew members and corporate teams often travel to offshore rigs, oil platforms, or remote exploration sites.

 Complex Itineraries: Travel often involves multiple legs, charter flights, and lastminute changes due to operational demands or adverse conditions.

 Safety and Compliance: Travel in high-risk regions requires stringent safety protocols and adherence to international regulations.

 Crew Rotations and Group Travel: Managing crew rotations and transporting large teams in a time-efficient and cost-effective manner is a major logistical challenge.

A solution that addresses these challenges while being accessible and innovative will only serve to streamline and consolidate business travel for groups of any size and within any industry. This is where ATPI steps in with our specialised travel management services and technologies, each tailored to the unique needs of the energy sector.

ATPI CrewHub

With over 100 years of experience in complex travel logistics and solutions, we developed our proprietary booking platform, ATPI CrewHub, after identifying a significant gap in the market.

Initially developed as a pioneering solution exclusive to our Marine and Energy customers, we quickly realised the technology’s broader potential, extending its functionality to meet the requirements for all types of crew and groups we work closely with. Designed to transform

your approach to group travel, ATPI CrewHub provides full autonomy of your journey to allow users to book via one inclusive platform for teams travelling from multiple locations globally - making it the perfect companion for the energy sector’s crew rotations.

In recognition that no two journeys are alike, CrewHub allows users to book multiple different routes with several people per route per booking. Designed with operational efficiency and cost saving in mind, the platform enables you to filter flights to meet your unique requirements, tailoring each trip to suit your needs perfectly.

Through CrewHub, those responsible for travel arrangements can now select names, dates, arrival and departure locations, and routes and fares in one transaction. Differentiating the platform from traditional online booking tools, CrewHub includes options for specialised requirements to aid offshore workers and crews in accessing remote locations and flexible schedules, while also ensuring all bookings and itineraries are reviewed and validated alongside an ATPI agent to provide customers with the reassurance that all details are accurate and compliant with their travel requirements.

This development will speed up, simplify, and modernise crew and group travel to empower operators.

Key Features of ATPI CrewHub:

 Operational Efficiency and Workflow Gains - Streamline the travel booking process to deliver significant efficiency gains by increasing productivity for booking coordinators.

 Cost-Saving Measures - Filter flights based on cost and duration to secure the most cost-effective options.

 Multiple Start Points – Streamline the travel process by booking an unlimited number of travellers from multiple start points across the globe on one booking.

 Single Sign-On for Easy Access - Integrate with ATPI TravelHub to provide a single signon and simplify the booking process.

Our deep understanding of the energy sector’s travel needs ensures that companies can rely on solutions tailored specifically for them. Embrace the future of crew travel management with our exclusive platform, where convenience and customisation come together effortlessly.

Delegates trained every year 8 Training centres in the UK

The highest-impact, safety-critical training.

3t Training Services is the UK’s largest and leading provider of safety-critical training for energy, renewables, power, and industrial industries.

When you train with 3t, you are learning from industry experts - professionals with extensive hands-on experience who are passionate about workplace safety and committed to helping you and your workforce reach your full potential.

Train yourself or your workforce at one of 3t’s eight state-of-the-art training centres across the UK.

Backed by our own global training management solutions, we offer bespoke and flexible training tailored to your project requirements and timelines. Our expert-led programs help you plan, stay safe, and enhance your skill set in this fast-growing sector.

At 3t, we don’t believe in one-size-fits-all training. Our flexible, expert-led solutions are built around your needs.

Discover the right training for you at 3tglobal.com/training-services