OGV Energy Issue 89 - Subsea by OGV Energy

Hello and welcome to the ‘Subsea’ issue of OGV Energy Magazine. A big ‘Thank you’ to Rotech Subsea for sharing their journey with OGV as they hit a milestone 30 years! We are also delighted to showcase contributions in this month’s edition from GDi, Pipetech, PTS Services, Elementz, Viper Innovations, Fujifilm and many others.

As always, this issue provides a thorough review of the energy sector across the North Sea, Europe, the Middle East, and the USA and you’ll also find insightful articles from Brodies LLP and Leyton, as well as project updates from the EIC, and Renewables UK

We are really looking forward to attending Subsea Expo this month, where we will be distributing the publication and engaging with the delegates. Hope to see you there!

Enjoy this issue!

30 years of innovative solutions

Rotech Subsea, the pioneer and leading provider of Controlled Flow Excavation (CFE) and suspended jet trenching technologies, is proudly celebrating its 30th anniversary.

With a rich history of innovation and technological development, Rotech Subsea is a perfect example of a business that has successfully evolved and adapted with changing market and client demands to remain at the forefront of the subsea sector.

The Rotech journey began in 1994, with the business acquiring Volker Stevin Offshore (VSO), a North Sea focused fabrication services provider. Combined with Rotech’s in-house engineering capabilities, this acquisition provided the initial foundations to develop and build the business’s first two technologies, the Flowdredger mass flow excavation device and MacDrill downhole motor, which was licensed to Wetherford just four years later.

1998 saw the achievement of a significant technological advancement, successfully completing the first commercial field trial of a new ‘T-shaped’ mass flow subsea excavation system. This paved the way for the formation of Rotech Subsea, completing its first pipeline post-trenching scope that very same year. Following a successful 13 year period, Rotech sold its first generation tools in a high profile sale to REEF Subsea.

But this was just the beginning of the story. Emerging from a non-compete period in 2015, Rotech re-entered the market, a phase Rotech

employees coined ‘Rotech 2.0’. Over the next few years, Rotech’s research, development and engineering team introduced an entire suite of new tools, the RS range of excavators, which have become the market leaders in non-contact Controlled Flow Excavation.

The RS range was developed using the latest Computational Fluid Dynamics and Computer Aided Design techniques. The results provided significant operational, efficiency and safety benefits. Pioneering the industry’s first Controlled Flow Excavation technology, designed, built and operated in-house, Rotech Subsea was able to offer clients an enhanced solution capable of supporting operations across the entire project lifecycle.

of subsea assets. In the past we only really had one tool that tried to do everything, whereas now we have a series of tools and combinations, meaning we can offer a wide variety of tailored solutions to clients.”

the evolution of equipment from mass flow to controlled flow enabled us to offer a lot more to clients through our hybrid systems.

Global Business Development Director, Stephen Cochrane adds “the evolution of equipment from mass flow to controlled flow enabled us to offer a lot more to clients through our hybrid systems. Our excavators can cope with really soft soils to very hard materials, which really established us as a serious competitor in the burial and deburial

Continuing to demonstrate its capability to innovate, Rotech added its unrivalled ‘RS3’ to its portfolio in 2023. According to Dr Donald Stewart, Rotech’s MD, “before the RS3 the maximum pressures available were of the order of 50 kPa. With the RS3 capable of operating in pressures up to 350 kPa we have opened up entirely new applications previously beyond the reach of non-contact methods.” Purpose-designed for cutting narrow trenches in harder soils, the innovation marked a significant enhancement compared to existing technologies on the market.

With such an extensive range of solutions, Rotech is uniquely positioned to support clients across the entirety of the project lifecycle, from pre-commissioning and commissioning to inspection, repair and maintenance and eventual decommissioning. This has enabled

the business to capitalise on rapidly growing work scope requirements such as route clearance and trenching, subsea asset burial/ de-burial and cutting and recovery.

To this day, Cochrane marks Rotech’s reentry to the market as one of its proudest achievements. “We had a clean slate, a new drive and ambition, and unparalleled experience. Winning that first opportunity back in 2015 and convincing the client that we were still the best in the sector took a lot of trust for them to allow us to come in to execute those campaigns, and it’s from that base that we have grown.” Fast forward 10 years, and the business has successfully completed over 600 projects globally and grown its suite of tools to over 30 systems.

Whilst ‘Rotech 2.0’ signified an era of change for the business, a constant that never withered was the core values of Rotech. What began as a family-orientated business still very much maintains this culture today, focusing on collaboration and personal development across the business. “We’ve always encouraged our people to develop ideas and to be free and open, and we collect ideas and opinions from right through the

company. We want people to enjoy coming to work and that’s one of the real joys of working at Rotech, providing the opportunity to take something from a conceptual idea, taking this out into the workshop and fabrication shop to be built, and then operating it offshore. From start to finish this is all Rotech, everybody feels they have made a contribution to the process, and that’s very exciting to see.” says Stewart.

30 years at the forefront of the subsea sector has earned Rotech Subsea an exemplary reputation, something that they are immensely proud of. Stewart adds “We are very proud of the reputation that Rotech has all over the world. We are very honest about our equipment, its performance, its capabilities, and the result is that our customers trust us when we say that we can deliver for them. So when people see the Rotech logo, they know that they are going to get a good quality product, a great service, and at every stage of the process Rotech will go out of their way to make sure that the client gets the result that they are looking for.”

As Rotech has developed, so too has the energy sector. Back in 1994, renewables were generating less than 2% of the UK’s electricity.

Fast forward 30 years, and this figure is 50% and rising. Combined with technological advancements, Rotech has made a conscious effort to adapt to these changing landscapes. Cochrane adds “The industry has definitely changed. You can really put yourself on the global map with a click of a button with things like social media, and we can cope with that because we’ve grown, we’ve developed, we’ve got good people Central, East and West to cope with the market growth.”

And grown they have. A first-mover in offshore wind, Rotech Subsea has established an enviable track record within the sector. Accounting for around 98% of 2024 revenues, Rotech Subsea is very much at the forefront of the energy transition.

With a strong order book running well into 2025 and beyond, Rotech continues to establish a strong international presence across established and emerging regions both East and West, notably Taiwan and the USA.

Rotech has been involved from the early stages of the rapidly developing offshore wind market in Taiwan, and has continued to benefit from sustained activity across the region. Contributing to a notable percentage of 2024 revenues, Rotech saw record levels of demand across the year, with five equipment spreads mobilised at one time within the region. Having first established roots incountry in 2020, the company significantly increased the size of its service offering last year to keep up with local demand.

Having worked on every major operational windfarm to date, Rotech has already established a strong operational track record in the US. Following the announcement of its newly incorporated US entity and office in Providence, Rhode Island last year, the company is well positioned to support its client base with equipment spreads based in-country. Continuing to build on its existing cable trenching successes, the US market offers another huge opportunity for global growth.

As Rotech Subsea celebrates this significant milestone, the business would like to thank its long-standing customers for their continued trust and custom. Rotech takes great pride in supporting the development of critical subsea infrastructure globally, and look forward to continuing to collaborate with clients to achieve this for years to come. 

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COMMUNITY news

Motive Offshore cements

Americas presence with Texas expansion

Motive Offshore Group (Motive), which specialises in rental, inspection and engineering equipment for the energy sector, announces the opening of its new office in Houston, Texas, following a fourfold increase in its equipment for the Americas. This strategic expansion will support increasing operational demands and sets the stage for continued growth.

Critical Nuclear Inspections Ensure Safety and Efficiency

The Houston facility will serve as a central hub for Motive’s operations in the Americas and reinforce its increased local capabilities, achieved through key acquisitions and the relocation of important equipment. This initiative is critical for accompanying the company’s comprehensive approach to providing rental equipment solutions and delivering an integrated end-to-end service.

JW Automarine Ltd (JWA Group), the market leader in the radio frequency welding of PVC & PU fabrics, is proud to announce its JOSCAR supplier accreditation. This significant milestone demonstrates the company’s unwavering commitment to maintaining the highest standards of compliance and risk management within the aerospace and defence sectors.

JOSCAR, the Joint Supply Chain Accreditation Register, is an accreditation system recognised by major buyers in the aerospace, defence, security, and space industries. By achieving this accreditation, JW Automarine aligns itself with industry leaders who prioritise quality, safety, and responsible business practices.

OEG and COENS sign MoU to offer renewable service solutions to offshore wind market in South Korea

OEG Energy Group Limited (“OEG”, the “Group”), a leading energy solutions business, is pleased to announce the signing of a Memorandum of Understanding (“MoU”) between OEG Renewables and COENS Co., Ltd (“COENS”) in relation to the provision of pre-construction, construction, installation, and operations and maintenance (“O&M”) services to offshore wind projects in South Korea.

The partnership between OEG and COENS combines OEG’s experience in delivering offshore energy solutions and COENS’ extensive incountry capabilities and resources to target the South Korean offshore wind market which is experiencing positive market drivers and significant growth potential.

LHR Marine Limited is delighted to announce the successful extension of a significant contract with a major subsea technology company. This extension underscores LHR Marine’s position as a trusted leader in the management, supply, and servicing of fall protection equipment—an area where safety and reliability are non-negotiable. This renewed partnership highlights the exceptional dedication, expertise, and commitment of the LHR Marine team to delivering top-quality products and services. The extension not only reflects our unwavering focus on safety and innovation but also reaffirms the valued trust placed in us by our longstanding partner.

Sustainable drilling waste solutions recognised in prestigious industry awards

Specialist drilling waste management company, TWMA*, has been announced as a finalist in this year’s SPE Offshore Achievement Awards. Shortlisted for the Sustainability Project Award, this recognition celebrates TWMA’s RotoMill®** technology, an innovative offshore processing solution that decarbonises drilling waste operations by more than 50%.

Now in its 38th year, the Offshore Achievement Awards is the largest and longest established industry awards for the UK offshore energy sector. This nomination is a testament to TWMA’s commitment to cutting operational emissions and supporting a circular economy through the reuse of recovered oil.

The Engineering Construction Industry Training Board (ECITB) has allocated £300K for temporary workers within the engineering construction industry (ECI) to verify their base level of technical competence as part of the Connected Competence scheme.

Connected Competence assures an ongoing base level of technical competence through industryrecognised, standardised testing to create a safer, technically competent and transferable workforce.

Temporary workers who are working (or seeking work) with Connected Competence employers can access technical test vouchers that enable them to complete the tests free of charge.

JW Automarine achieves JOSCAR accreditation

LHR Marine Secures Two-Year Contract Extension with Leading Subsea Technology Company

£300K for Connected Competence voucher scheme

LATEST OGV COMMUNITY SIGN-UPS

The purpose of Integrity HSE is to make our client’s working world a safer, healthier and more sustainable place for all. Our company distinguishes itself from the competition by pairing what is recognised as the best HSE and training professionals anywhere in the world with client challenges.

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For over 40 years, we have ensured that our customers can realize the full potential of their assets. Our passion for innovation drives us to develop cutting-edge technology solutions that deliver profound insights, extend asset life, and optimize performance. Our deep expertise across diverse technology fields, combined with advanced digital and AI capabilities, ensures that you make the best decisions for your unique needs.

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Motive supply every aspect you need; from equipment design and build, to inspection and testing, through to equipment mobilisation and operation, we offer all the ‘tools’ necessary to complete your project successfully and on time, along with a friendly, knowledgable team 100% invested in delivering your solution.

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Centurion offers customers in the critical industries efficient, safety-driven rentals, sales and services.

With a strong and established presence in the UK & Europe region, Centurion delivers best-in-class, tailored rental packages to meet customers’ precise needs in an efficient and cost-effective manner – no matter the size or scope of the job.

www.centuriongroup.co.uk/

Bilfinger is an international industrial services provider. The aim of the Group’s activities is to increase the efficiency and sustainability of customers in the process industry and to establish itself as the number one partner in the market for this purpose.

www.bilfinger.com/en/

We bring sensing, analytics and engineering together.

ONYX Insight is an award-winning global, renewable, technology business. We bring unbiased predictive analytics underpinned by real-world engineering expertise to owners and operators of renewable energy assets via 7 global offices and 10 patents.

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We are an award winning engineering consultancy specialising in the energy sector. We have capabilities across all major engineering disciplines to support the full project lifecycle from concept development to execution. We provide technical expertise through our four main service lines.

gaps. www.oci-group.co.uk/

www.ecitb.org.uk

Elementz is shaping the future of Subsea Asset Integrity Management (AIM) with our leading-edge integrity software, Integrity Elementz. The Elementz Software-as-a-Service (SaaS) solution is redefining the standard in Subsea Integrity and Inspection Management software, empowering organisations to navigate the complexities of subsea asset integrity management with confidence and efficiency.

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online

UK North Sea Energy Review

By Tsvetana Paraskova

Donald Trump’s barb at the UK’s energy policy, the state and prospects of decommissioning in the basin, and many contract awards and field development updates featured in the UK North Sea oil and gas industry in the past month.

The UK offshore energy industry body, OEUK, responded to Trump’s post, saying that “The UK needs a diverse energy mix from the North Sea including oil, gas and offshore wind. Total energy production in the UK is at record lows with the country reliant on energy imports of oil, gas, and electricity for almost 40% of domestic energy demand.”

“It’s essential to attract investment across the energy mix to meet the nation’s energy needs and keep jobs, firms and their supply chains here in the UK, the industry body said.

“The best way to protect consumers and provide secure affordable energy is to produce as much of it as we can in the UK.”

The UK’s underwater industry has grown in recent years, but it needs certainty in new project timelines and execution to sustain this growth, research from Global Underwater Hub (GUH) revealed in December.

The world-leading underwater industry has grown from £8 billion to £9.2 billion and now supports over 51,000 jobs, GUH said.

Yet, its study found that the industry has both the capacity and capability to accelerate the global energy transition but only if project certainty is secured.

across all its markets, particularly in offshore energy,” said Neil Gordon, GUH chief executive.

“It is closing the gap towards having the necessary capacity to meet demand but does not have sufficient confidence in project timelines and returns to trigger the necessary investment.”

According to Gordon, the industry needs “aligned policy, timely consenting, sensible financing, concrete project timelines and clear supply chain investment” to move projects forward.

The North Sea Transition Authority (NSTA) has imposed a penalty of £125,000 on CNOOC Petroleum Europe Limited for venting without consent at its Buzzard field, 60 miles northeast of Aberdeen, on two separate occasions in the space of a fortnight. This was the latest NSTA action to crack down on excessive flaring and venting in the UK North Sea. CNOOC Petroleum Europe became the sixth North Sea operator to have been fined for excessive flaring or venting in the past two years as the industry regulator continues its crackdown on those who breach agreed limits.

In early January, Trump, while he was still the US President-elect then, took to social media to criticise the energy policy of the UK government.

Trump called for opening up the UK North Sea to oil and gas and “getting rid of windmills”, in response to the recent announcement by Texas-based Apache that it would cease oil and gas production in the region due to the uneconomical windfall tax.

“The U.K. is making a very big mistake. Open up the North Sea. Get rid of Windmills!” Presidentelect Trump posted on social media platform Truth Social.

The post contained an attached article about Apache’s recent announcement that it would exit the UK North Sea.

There is a more positive assessment of supply chain capacity and, overall, market prospects remain high, driven by the wide range of opportunities across all its markets, but most notably, in offshore energy, according to the 2024 Business Survey from the leading trade and development body for the UK’s underwater industry.

But confidence in whether or when projects will be delivered has declined – 62 percent of respondents believe that project timelines will be missed.

The lack of project surety and a “concerning” uncertainty about timelines is making it tough for companies to tie business and investment plans back to Final Investment Decisions (FIDs), tender awards, and project sanctions, according to GUH.

“Our world class underwater supply chain rightly sees itself as having the necessary, leading capability to harness the opportunities

Since the end of 2022, the NSTA has now issued fines totalling £825,000 for flaring or venting consent breaches. The regulator urged operators once again to ensure compliance with regulations.

“North Sea operators have taken up the challenge of cutting flaring and venting, almost halving emissions from these processes since 2018,” Jane de Lozey, NSTA Director of Regulation, said.

“However, at a time when the industry is competing for investment, and its commitment to the energy transition is under intense scrutiny, it is vital that all operators remain vigilant on emissions.”

A series of technical, logistical, legal, regulatory, commercial, and financial complexities will likely lead to continued delayed decommissioning on the UK Continental Shelf, despite the fact that the windfall tax has accelerated decommissioning for some assets, Wood Mackenzie said in an analysis.There is growing evidence in the decommissioning sector of supply chain

constraints and rising costs in an industry which Wood Mackenzie estimates will be worth US$58 billion, or £41 billion, in real terms through to the early 2060s.

WoodMac has estimated 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.

Moreover, accelerated decommissioning can strain the ability of smaller companies to meet their obligations for shutting down assets, increasing the risk of defaults, the report found.

In a worst-case scenario, where a company defaults and there are no other parties to pick up the bill, liability would fall to the UK taxpayer, WoodMac said.

“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,” noted James Reid, Senior Research Analyst at Wood Mackenzie.

In company and project news, TotalEnergies announced the sale to EPUKI, the UK subsidiary of EPH, of 50 percent of its shares in West Burton Energy, a company wholly acquired in June 2024 with the announced intention to resale one half.

West Burton Energy owns a 1.3 GW gas-fired power plant and a 49 MW battery storage system in the United Kingdom. The plant will be operated by the joint venture between TotalEnergies and EPUKI.

Ithaca Energy and Harbour Energy found gas condensate at the Jocelyn South prospect (P032) in Block 30/07a, located in the UK Central North Sea.

UK ENERGY REVIEW

The process of restarting Triton took longer than expected, which, together with a short period of unscheduled downtime on the Bruce platform, meant that Serica’s 2024 production averaged 34,600 boepd across the year.

“Production in the second half of 2024 was clearly disappointing and well below the potential of our asset base,” Serica’s CEO Chris Cox said.

“We and our partners are working to improve planning and procedures to optimise maintenance and maximise production resilience going forward.”

SLB, the world’s top oilfield services and energy technology provider, has been awarded a series of major drilling contracts by Shell to support capitalefficient energy development across its deep- and ultra-deepwater assets in the UK North Sea, Trinidad and Tobago, the Gulf of Mexico, and others.

The projects, which will be delivered over a threeyear timeframe, will combine SLB’s AI-enabled digital drilling capabilities with its expertise in ultradeepwater environments, SLB said in early January.

PDi has won a contract by EnergyPathways to provide engineering study support to its Marram field development project in the UK Irish Sea. PDi said it would work closely with the EnergyPathways team to guide decision-making on its subsea tie-in connection of the Marram development.

We and our partners are working to improve planning and procedures to optimise maintenance and maximise production resilience going forward.

The Operator, Harbour Energy, intends to complete data gathering and evaluate the drilling results to establish commerciality of the reservoir.

Jocelyn South forms part of the Harbour Energy operated J-Area, where Ithaca Energy is a partner in the Jade field, Judy field, Jasmine field, and the Talbot field which recently achieved first production in November 2024.

Serica Energy plc has signed an agreement to buy 100 percent of the shares in Parkmead (E&P) Limited from Parkmead Group Plc, which includes a 50- percent working interest in licence P2400 (Skerryvore) and a 50- percent working interest in licence P2634 (Fynn Beauly), for an initial consideration of £5 million.

Serica also said that production into the Triton FPSO resumed on 27 December with a phased restart of the producing and new wells ongoing. Importantly, following extensive root cause analysis and remedial work, the export gas compressor was restarted successfully and gas exports commenced on 29 December.

EnergyPathways’ Marram underground geo-storage capacity is projected to be up to 50 billion cubic feet of gas and is developing integrated energy storage that can provide the UK with secure flexible gas supply and leverage the growing value loss from the UK’s excess wind power by utilising green hydrogen storage solutions.

KCA Deutag has been awarded a total of $513 million in land and offshore drilling contracts, including $16 million in contract extensions in the UK where the company continues to be a trusted drilling partner to operators in the North Sea. KCA Deutag’s new land and offshore drilling projects are located in the Middle East, Africa, Latin America, and the UK. 

Europe Energy Review

By Tsvetana Paraskova

Moscow has said that it would be open to talks, but Ukraine’s leadership has been warning for months that no deal would be pursued with Russia.

The end of decades of Russian pipeline natural gas flows to Europe via Ukraine, new discoveries offshore Norway, records in UK clean electricity, and a number of green energy deals marked the end of 2024 and the beginning of 2025 in Europe’s energy sector.

Oil & Gas

On New Year’s Day Russian gas giant Gazprom stopped sending natural gas to Europe via a pipeline in Ukraine, after Kyiv refused to negotiate and pursue an extension to the gas transit deal with Russia. The gas supply deal for Russian gas to Europe transiting Ukraine expired on December 31, 2024.

Austria, Slovakia, and Hungary were the European customers that continued to receive Russian gas after 2022, but their supply via Ukraine stopped on January 1, 2025.

Hungary will continue to receive Russian gas via the TurkStream gas pipeline via Turkey and the Balkans, while Austria and Slovakia have arranged to have natural gas from other sources supplied.

In another Russia-related development, the Joint Expeditionary Force (JEF) has activated an advanced UK-led reaction system to track potential threats to undersea infrastructure and monitor the Russian shadow fleet, following reported damage to a major undersea cable in the Baltic Sea, the UK government said in early January. The 10-nation strong Joint Expeditionary Force, of which the UK is the framework nation, activated the system named Nordic Warden, which will alert partners and NATO of any ships deemed a risk to key areas of interest. Nordic Warden was launched after a suspected Russian shadow fleet tanker damaged subsea power and data cables between Finland and Estonia at the end of December.

Nordic Warden will use AI to assess data from a range of sources, including the Automatic Identification System (AIS) ships use to broadcast their position, to calculate the risk posed by each vessel entering areas of interest.

In field discovery and development news, Equinor announced an oil and gas discovery west of the giant Troll field in the North Sea. The discovery is currently estimated at between 2 and 12 million barrels of oil equivalent.

“It’s a small discovery, but in an interesting area that we plan to further explore with much existing infrastructure,” said Geir Sørtveit, Equinor’s senior vice president for Exploration & Production West on the Norwegian continental shelf (NCS).

“If more discoveries are made, it may be relevant to combine these to ensure good resource utilisation and the best possible economy.”

Equinor has also said that the Troll field in the North Sea produced more gas in 2024 than ever before, while CO2 emissions were significantly reduced.

The 42.5 billion standard cubic metres of natural gas produced at Troll in 2024 marked the highest annual production ever for the field, and a 10-percent increase from the previous record from 2022 (38.8 billion standard cubic metres).

Aker Solutions has signed a contract to deliver maintenance and modification services for Vår Energi’s Jotun, Balder, and Ringhorne assets in the southern area of the Norwegian Continental Shelf.The fiveyear agreement includes an option for Vår Energi to extend the contract by up to three additional two-year periods.

Also offshore Norway, OKEA has entered into an agreement with DNO Norge to swap a 10-percent working interest in PL 1119 containing the Mistral prospect, for a 10-percent working interest in PL 1109 containing the Horatio prospect.

Low-Carbon Energy

Wind was the largest source of electricity generation in Britain in 2024 for the first year ever, accounting for 30 percent, the National Energy System Operator (NESO) said in its 2024 Review of the electricity market.

Moreover, renewables generated more than 50 percent of Great Britain’s electricity for four consecutive quarters (Q4 2023 – Q3 2024) for the first time, averaging 51 percent last year. Also in 2024, the UK saw a monumental change in its power generation profile as the last coal-fired power plant was switched off, ending 142 years of coal-powered electricity.

The UK and Norway launched in December a new Green Industrial Partnership to combine their world-leading capabilities on clean energy, drive economic growth and deliver on the UK Prime Minister’s Plan for Change. The partnership will see enhanced cooperation across a range of sectors, including future clean energy innovation, the UK government said.

Mark Wilson, HSE & Operations Director at UK’s offshore industry body OEUK, commented:

“The UK has had a long and successful energy partnership with Norway, and this will continue as the North Sea builds out future needs in carbon capture and storage, hydrogen and floating wind as well as the oil and gas we will continue to need.”

“These are deeply interconnected markets not just for the energy we produce and use but also for the flow of people, skills and technologies in the North Sea basin,” Wilson added.

A new report from the Institute for Public Policy Research (IPPR) has called for a “fournations approach” to secure the UK’s wind energy future.

The UK needs greater input from the devolved nations on key issues currently determined by the UK government, such as building grid infrastructure, regenerating ports, and developing new supply chains, the report highlights.

The recommendations in the report include the four nations working together to coauthor a shared energy acceleration strategy, as well as creating an All-Nations Renewables Team to implement the strategy, reporting to the Joint Ministerial Committee on Net Zero.

Renewables provided nearly half of electricity in Ireland in December, provisional data from grid operator EirGrid showed.

A total of 46.7 percent of Ireland’s electricity came from renewable energy sources in the

last month of 2024, with wind at 41.4 percent, according to the data.

The share of non-renewable sources stood at 41.4 percent, while net imports provided the remaining 12 percent of Ireland’s electricity in December.

“Wind energy contributed strongly to electricity generation last month, marking one of the highest December figures for wind energy generation on record,” said Diarmaid Gillespie, Director of System Operations at EirGrid.

The EU achieved the cleanest power generation mix ever in 2024, as the share of renewables continued to grow, according to Eurelectric, the federation of the European electricity industry.

Renewables contributed 48 percent of the EU power generation mix, followed by nuclear at 24 percent and fossil fuels at 28 percent – the lowest share ever, Eurelectric said. Last year also marked the lowest emissions from the EU power sector with a 13 percent drop compared to 2023.

Although EU power demand grew by nearly 2 percent in 2024 compared to 2023, it remains lower than pre-crisis levels, Eurelectric noted.

in 2024, up from 12 percent in 2023.

In green energy projects, Copenhagen Infrastructure Partners (CIP) said in early January that it had become the UK’s largest battery storage investor, with the start of construction of two new Battery Energy Storage Systems (BESS), the largest of their kind in Europe. CIP took the final investment decision to begin construction of the Coalburn 2 and Devilla BESS in Scotland.

These two projects represent an investment of approximately £800 million. They expand CIP’s UK BESS construction portfolio from one to three projects and make CIP the largest battery storage investor in the United Kingdom.

CIP’s portfolio of three projects – Coalburn 1, Coalburn 2, and Devilla – will have total power capacity of 1.5 GW and will be able to store and supply the grid with a total of 3 GWh of electricity, equivalent to the electricity demand of over 4.5 million households, across a 2-hour period.

Wind energy contributed strongly to electricity generation last month, marking one of the highest December figures for wind energy generation on record...

In Germany, the share of renewables also jumped in 2024 and accounted for 59.0 percent of total generation, compared to 56 percent in 2023, the federal network agency Bundesnetzagentur said.

Wind accounted for the largest share of total generation among all energy sources, with 111.9 TWh from onshore wind and 25.7 TWh from offshore wind, up from 23.5 TWh offshore wind generation in 2023.

The German solar industry passed the 100 GW threshold of solar power installations, according to data compiled by the local solar industry association, Bundesverband Solarwirtschaft. Solar power accounted for 14 percent of German electricity consumption

Aker Solutions and ABB have been awarded a front-end engineering and design (FEED) contract for the GreenVolt offshore wind project offshore Scotland. The 560-MW project is a collaboration between Vårgrønn and Flotation Energy, and aims to establish the first commercial-scale floating wind farm in Europe and will contribute to the UK’s ambitions to become a world leader in floating offshore wind.

Harbour Energy and its project partners announced a final investment decision (FID) for the Greensand Future carbon capture and storage (CCS) project in Denmark. The project will store carbon dioxide from Danish emitters in a depleted oil field under the Danish North Sea. Harbour holds a 40 percent non-operated interest, alongside operator INEOS E&P A/S with 40 percent and Nordsofonden with 20 percent, in the Greensand Future project. 

USA Energy Review

By Tsvetana Paraskova

The US oil and gas industry is welcoming the new Administration with more optimism and the outlook of producers and service providers has brightened over the past few weeks.

fundamentals, executives said in the closelywatched Dallas Fed Energy Survey for the fourth quarter of 2024.

Outlook in the Shale Patch Brightens

According to the survey, activity in the oil and gas sector rose slightly in the fourth quarter 2024, while the company outlook index turned positive.

The business activity index, the survey’s broadest measure of the conditions energy firms face in the Eleventh District, increased from -5.9 in the third quarter to 6.0 in the fourth quarter. Optimism also increased, as the index jumped by 19 points from the negative -12.1 in the third quarter to 7.1 in the fourth quarter. The outlook uncertainty index, on the other hand, declined by 26 points to 22.4.

Oil and gas production was mixed in the fourth quarter, executives at exploration and production (E&P) firms said in the survey. The oil production index remained positive but declined from 7.9 in the third quarter to 1.1 in the fourth quarter, suggesting oil production was relatively unchanged during the period. Meanwhile, the natural gas production index remained in negative territory but rose from -13.3 to -3.5, indicating gas production edged lower.

Costs in the shale patch increased at a similar pace in Q4 compared to the previous quarter. At the same time, the lease operating expenses index increased slightly, from 21.3 to 25.6.

Oilfield services firms reported weakening conditions, although the weakening happened at a slower pace, according to the survey. The equipment utilization index for oilfield services firms remained in negative territory, improving from -20.9 in the third quarter to -4.4 in the fourth quarter, suggesting the pace of the decline slowed significantly.

Net hiring in the oil and gas sector remained muted, as the aggregate employment index was relatively unchanged at 2.2 in the fourth quarter. While this is the 16th consecutive positive reading, the low-single-digit result suggests little net hiring, the survey showed.

On average, respondents expect a West Texas Intermediate (WTI) oil price of $71 per barrel at year-end 2025, with responses ranging from $53 to $100 per barrel. Longer term, respondents on average expect a WTI oil price of $74 per barrel two years from now and $80 per barrel five years from now.

In the natural gas market, survey participants anticipate a Henry Hub natural gas price of $3.19 per million British thermal units (MMBtu) at year-end 2025. Respondents on average anticipate a Henry Hub gas price of

$3.63 per MMBtu two years from now and $4.16 per MMBtu five years from now. For reference, WTI spot prices averaged $70.66 per barrel during the survey collection period, and Henry Hub spot prices averaged $3.04 per MMBtu.

Capital Spending Rising in 2025

Most executives in the survey expect their firm’s capital spending to rise in 2025 compared with 2024. A total of 43 percent of executives said they expect capital spending to increase slightly, while an additional 14 percent anticipate a significant increase. Another 19 percent expect spending in 2025 to remain close to 2024 levels, while 23 percent anticipate reductions in spending in 2025.

The average WTI price which executives use for planning capital expenditures in 2025 was $68 per barrel, with the median and the mode at $70 per barrel. The average price used is slightly below the price used in the budget in 2024 at $71.

Of E&P firms expecting to raise capital investment in 2025, a total of 68 percent said they would invest more in drilling and completion, 29 percent would boost spending on acreage, including M&A, and 25 percent each said they would invest more in exploration and selected “other.”

Optimism Returns

With the new Administration, most executives expect permitting times for drilling wells on federal lands to improve over the next four years, according to the survey.

Comments from the survey participants showed optimism about regulations but continued concerns about rising costs.

“Production for our firm has decreased with increased costs to remediate production issues with the prospect of lower crude oil prices,” one E&P executive said.

Another noted, “The new administration should have a positive effect on the economy, thus lifting the oil industry.”

A third executive said “We are anticipating that regulatory compliance issues will decrease, primarily due to an incoming administration that is pro-business and pro-fossil-fuel production.”

Yet, another pointed out that “Higher interest rates discourage long-term capital investments.”

Overall, optimism has increased and company outlooks improved in anticipation of an administration friendlier to the industry.

Among oilfield services firms, one executive said that “The end-of-year slowdown in onshore activity is greater than anticipated.”

Another commented, “We expect the ban on permits for LNG export terminals to be lifted, which will eventually lead to stabilizing natural gas prices and reduced barriers to oil production via providing a market for the associated gas production. Of course, all of this is very optimistic and hinges on a combination of OPEC control and improvement in the Chinese economic situation.”

Oil Lobby Reveals Policy Roadmap

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

API’s five-point policy roadmap details steps the new Administration can take in the coming years to protect consumers, bolster geopolitical strength, leverage US national resources, reform the permitting system, and advance sensible tax policy.

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

API’s policy suggestions for protecting consumer choice include repealing the Environmental Protection Agency’s (EPA) tailpipe rules, repealing the National Highway Traffic Safety Administration’s Corporate Average Fuel Economy (CAFE) standards, and denying or rescinding EPA’s Waiver for California’s Advanced Clean Cars II (ACCII) rule.

To bolster America’s geopolitical strength, API calls on the US President to lift the Department of Energy’s (DOE) LNG permitting pause, swiftly process all pending export applications now languishing at DOE, and ensure the open access of American energy to global markets.

In order to leverage US natural resources, the new Administration should issue a new Bureau of Ocean Energy Management (BOEM) five-year offshore leasing program, repeal restrictive onshore leasing rules, and end EPA’s methane fee that misinterprets Congressional intent and does little beyond increasing the cost of production for American oil and natural gas, API says.

Our country has a generational opportunity to fully leverage U.S. energy leadership to improve the lives of all Americans and bring stability to a volatile world.

The US permitting system could be reformed through reform of the National Environmental Protection Act (NEPA) and the Clean Water Act, as well as through advancing judicial reform and repealing the Biden-era NEPA rules.

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

For a sensible tax policy, the new US President is urged to retain the 21-percent corporate tax rate to ensure global competitiveness, maintain and extend tax provisions for domestic infrastructure investment, and preserve crucial international tax provisions.

Middle East Energy Review

By Tsvetana Paraskova

Geopolitics is increasingly shaping the oil and gas supply from the Middle East while the OPEC+ alliance continues to curb its production at least until the end of the first quarter of 2025.

The increase in Saudi prices, which typically set the tone for the pricing to Asia of the other major oil producers in the Middle East, also comes as the Saudi Arabia-led OPEC+ group continues to curb supply to the global markets.

Meanwhile, tightening U.S. sanctions on Iran and expectations of further sanctions on the Islamic Republic’s oil exports under the Trump Administration have pushed Iranian oil floating storage to a four-month high, according to Kpler. Iran’s crude in floating storage offshore Malaysia and Singapore jumped in the final quarter of 2024 and early 2025, per the data compiled by Kpler.

Middle East Recoups Some Market Share from Russia in Asia

As a result of lower supply from Iran and also Russia, whose exports declined in the last weeks of 2024, the Middle Eastern producers have regained some market share from the two sanctioned exporters.

In November, Saudi Arabia’s oil exports to Asia rose, while Russia’s crude sales in the world’s most important oil-importing region fell amid lower purchases by Moscow’s two key markets, China and India.

Saudi Arabia Lifts Oil Prices To Key Market Asia

Saudi Arabia, the world’s largest crude oil exporter, raised in early January its official selling prices (OSPs) for February loadings for Asia, its top export market. The hike was the first in three months and came as the Middle East’s crude benchmarks, Oman and Dubai futures, strengthened at the end of 2024 amid declining supply from Iran and Russia following tightening U.S. and other Western sanctions. The OSPs of Middle Eastern crude going to Asia are priced against the Oman/ Dubai average.

Recovering Asian refining margins, a decline in the premium of the Dubai benchmark to Russia’s Urals, and rising shipping costs for Russia’s crude helped Saudi Arabia boost its crude oil supply to Asia by 550,000 barrels per day (bpd) in November, according to data from LSEG Oil Research.

Qatar Threatens to Halt LNG Supply to Europe over Sustainability Rule

Qatar, one of the biggest LNG exporters in the world, has threatened to halt supply to the European Union if the EU proceeds to fully implement its new corporate sustainability due diligence directive.

In 2024, the EU formally adopted the corporate sustainability due diligence directive. These new EU-wide rules introduce obligations for large companies regarding adverse impacts of their activities on human rights and environmental protection. The EU directive is part of the bloc’s efforts to align companies with which it trades with the goal of reaching net zero by 2050. The directive also lays down the liabilities linked to the company obligations in sustainability. If the companies with which the EU trades are found to be non-compliant on corporate sustainability, including environmental impact, they could be fined with 5 percent of their annual global revenues.

While Qatar stands in total support of the concept of the EU Corporate Sustainability Due Diligence Directive (CS3D), and of the desire to protect and uphold human rights, labour rights, and reducing environmental impact, “the issue is how you go about it,” said Saad Sherida Al-Kaabi, Qatar’s Minister of State for Energy Affairs, the President and CEO of QatarEnergy.

Al-Kaabi criticized the directive as “making absolutely no sense” in remarks at the Doha Forum 2024 in Qatar at the end of 2024.

“This directive affects any company that deals in Europe and makes more than €450 million generated in or from Europe. So, companies like QatarEnergy, Shell, or ExxonMobil and even car companies like Toyota or GM, will have to say they will abide by the Paris Accords. So, the company will have to commit to Net Zero,” Al-Kaabi said.

Deals and Contracts

Meanwhile, QatarEnergy has entered into an agreement with Harmattan Energy Limited (HEL), an indirect subsidiary of Chevron, to acquire a 27.5-percent working interest in an exploration block offshore Namibia. HEL will keep a 52.50-percent interest in the block. The other partners are Trago Energy Limited and the National Petroleum Corporation of Namibia (NAMCOR), each holding a 10percent interest.

Following successful drilling operations in our other acreage in Namibia, we look forward to soon begin drilling the first exploration well on this block

“For us as QatarEnergy, and with all the expansions we are undertaking, I can assure you we cannot meet Net Zero as a company.”

Added the minister and QatarEnergy’s CEO,

“We are also asked to be responsible for tier emissions 1, 2, and 3 and be liable for a penalty of up to 5% of our total generated revenue worldwide. This makes absolutely no sense. So, my message to Europe and to the EU Commission is: Are you telling us that you don’t want our LNG into the EU? Because I sure am not going to supply the EU with LNG to support their energy requirements and then be penalized with our total revenue worldwide.”

“So, I think what the EU is doing is really surprising, and I think it will harm them. And for companies that will have to comply, will need to put an army of people to do all this diligence. If there is more cost on the company to do this diligence, who ends up paying for it? The customer. This will harm European companies first,” Al-Kaabi said.

“Following successful drilling operations in our other acreage in Namibia, we look forward to soon begin drilling the first exploration well on this block,” QatarEnergy’s Al-Kaabi said.

As part of its LNG capacity expansion plan, QatarEnergy has selected the joint venture of Japan’s Mitsui O.S.K Lines Ltd and China’s COSCO Shipping LNG Investment (Shanghai) Co. Ltd. to own and operate six QC-Max size LNG vessels. The tankers will be built in China by HudongZhonghua Shipbuilding Group, a subsidiary of China State Shipbuilding Corporation (CSSC). These vessels are the last batch of the 128 LNG vessels in QatarEnergy’s historic ship building program, made up of 104 conventional and 24 QC-Max size ultramodern vessels.

“This is the last batch of long-term shipowner contracts in our 128-vessel strong historic shipbuilding program that will cater for QatarEnergy’s future LNG fleet requirements for our LNG expansion projects, as well as the replacement requirements of some of our existing fleet,” Al-Kaabi said.

Abu Dhabi’s national oil and gas firm ADNOC has signed a third Sales and Purchase Agreement (SPA) for the lower-carbon Ruwais LNG project. The deal was signed in December with Germany’s EnBW Energie Baden-Württemberg AG (EnBW), one of the largest operators of energy infrastructure in Germany and across Europe. The 15-year agreement for supplying 0.6 million tonnes per annum (mtpa) of LNG converts a previous Heads of Agreement between ADNOC and EnBW into a definitive agreement.

The LNG will primarily be sourced from the Ruwais LNG project, which is currently under development in Al Ruwais Industrial City, Abu Dhabi. Deliveries are expected to start in 2028 upon commencement of its commercial operations. To date, over 8 mtpa of the project’s 9.6 mtpa production capacity has been committed to international customers through long-term agreements, ADNOC says.

Upon completion, the project, comprising two 4.8 mtpa liquefaction trains with a combined capacity of 9.6 mtpa, will more than double ADNOC Gas’ existing operated LNG production capacity to around 15 mtpa.

Source: Gulf LNG

RCP-EDR

ELECTRONIC DRILLING RECORDER

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

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

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

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

1 YEAR AGO

1 Year Ago - $85.52

A nearly balanced market in the first part of the year and strengthening in demand were set to push the price of Brent Crude towards the $90 mark according to analysts. Geopolitical flare-ups and the disruption to commercial shipping in the Red Sea had been lending support to oil prices in recent weeks.

5 YEARS AGO

5 Years Ago - $54.70

It was five years ago this month that the first murmurings of Coronavirus began to worry many, with the biggest oil producers preparing to slash output. Representatives of OPEC and its allies were expected to meet as calls grew for action to support oil prices. The cost of crude hit its lowest level in a year after falling 20% since its peak the month prior

10 YEARS AGO

10 years ago - $60.33

Shell was to start the process which would lead to the dismantling of a platform on the Brent oil field in the North Sea. At its peak Brent, which was discovered in 1971, 115 miles east of the Shetland Islands, was producing half a million barrels a day, more than half Britain’s output at the time, but Shell decided to decommission the former cornerstone of the UK oil industry as its output had dwindled.

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BONGA NORTH TRANCHE 1

Following the final investment decision being taken in December, contracts have been formally awarded. TechnipFMC has been awarded a contract to supply Subsea 2.0 production systems for the project, while a consortia led by Saipem has an EPCI contract for risers, flowlines, subsea umbilicals and associated subsea structures.

KASKIDA OIL FIELD

Seatrium has been awarded the EPC contract for the construction of the Floating Production Unit (FPU) for the project. The Kaskida FPU features a single topside module supported by a fourcolumn semi-submersible hull and is designed to produce 80,000 barrels of crude oil per day from six wells in the first phase of development.

HIDAYAH OIL FIELD

A final investment decision has been reached on the project by Petronas. PT Casakha Engineering and its consortium partner PT Hafar Daya Konstruksi have been awarded the EPCI contract for the project. The scope of work will include Casakha overseeing the detailed engineering design for the pipeline, platform riser, PLET, and associated subsea components. The company will also be responsible for transportation and installation engineering.

FRAM SØR CLUSTER DEVELOPMENT

Subsea 7 has been awarded a FEED study contract, with an option to execute the project’s EPCI phase. The studies will be conducted at the company’s facilities in Norway and the UK to finalise the technical definition of the proposed subsea development. Should the EPCI be exercised in the future, Subsea 7 will handle the entire SURF installation scope.

ABU SAFAH FIELD –EXPANSION

Subsea 7 has been awarded a contract by Saudi Aramco under a long-term agreement. The contract scope includes the decommissioning of existing subsea facilities as well as engineering, procurement, construction, and installation of a new pipeline and subsea equipment.

BLOCK 52

Noble Corporation has secured a drilling contract with Petronas Suriname valued around US$84m. The Noble Developer rig, a highspecification semi-submersible unit currently stationed in Trinidad and Tobago, will drill three wells offshore Suriname, with the option to add one well. The assignment is expected to begin around June 2025 with an estimated duration of 200 days.

MOPANE 1X OILL DISCOVERY

Galp has successfully completed drilling and logging the Mopane-2A well, uncovering a hydrocarbon column of gas-condensate in the AVO-3 reservoir and light oil in the smaller AVO-4 reservoir. The company is now evaluating the commercial viability of these discoveries. Meanwhile, the drillship now moves to the Mopane-3X exploration well site, which is targeting two stacked prospects. Its results are expected in early February.

SILVERTIP SUBSEA TIE-BACK (PHASE 3)

Shell has announced the final investment decision (FID) for phase 3 of the Silvertip project, which will add two wells to increase Shell’s production at the Perdido spar in the US Gulf of Mexico. Subsea 7 has been awarded a contract to provide the engineering, procurement, construction, and installation of a production flowline and related subsea infrastructure for the project.

EXXONMOBIL-WOODSIDE JV BASS STRAIT DECOMMISSIONING PROGRAMME

ExxonMobil Australia has awarded Allseas the contract to use its single-lift installation and removal offshore construction vessel, “Pioneering Spirit,” to remove up to 12 retired platforms, consisting of 12 topsides and 11 steel jackets, totalling about 60,000 tonnes in weight, from the Gippsland Basin in the Bass Strait. The removal of the structures is scheduled to begin in late 2027 and last for three to four months.

HAI SU VANG FIELD

Murphy Oil announced the discovery of oil at the Hai Su Vang-1X exploration well in Block 15-2/17 in the Cuu Long Basin, offshore Vietnam. The well was drilled to a depth of 4,000 metretes in a water depth of 45 metres. The well encountered 112 metres of net oil pay from two reservoirs. Additional evaluation is currently ongoing with plans for appraisal drilling in the future.

SEA LION OIL FIELD (PHASE 1)

Aragon has secured a contract from Bluewater Energy for the front-end engineering and design (FEED) to redeploy the Aoka Mizu FPSO, currently operating in the Lancaster oil field. Refurbishment activities are scheduled to begin in 2025, with full operations expected in 2027.

ATAPU

(PHASE 2 – P84 FPSO)

Siemens Energy has secured a contract with Seatrium to supply all-electric, motor-driven compression packages for the P-84 and P-85 FPSOs. Siemens’ gear will utilise its DATUM compression technology to assist in reducing greenhouse gas emissions compared to conventional designs.

OIL FIELD

Global Subsea Market Set for Boost as Offshore Drilling Rebounds

By Tsvetana Paraskova

The upswing in offshore oil and gas exploration and development is set to boost the global subsea market in the coming years, while renewable energy projects, mostly offshore wind, in some areas are also expected to help the subsea supply chain.

Offshore Remains Economical New Source of Supply

Deepwater offshore, alongside US shale, remains one of the most economical new source of oil and gas supply, independent consultancy Rystad Energy said in a recent report.

Costs have jumped over the past two years, with the average breakeven cost of a nonOPEC oil project rising by 5 percent in the last year alone, to $47 per barrel of Brent crude, Rystad Energy research showed in October.

Despite rising costs, the average breakeven costs are still less than current oil prices, which were at about $75 per barrel Brent in early January.

Rystad Energy’s cost analysis has found that onshore Middle East is the cheapest source of new production, with an average breakeven price of just $27 per barrel.

Offshore shelf is the next cheapest new source of supply with a breakeven of $37 per barrel, followed by offshore deepwater at a $43 per barrel breakeven cost and North American shale with $45, according to the energy intelligence firm.

“Rising breakeven prices reflect the increasing cost pressures on the upstream industry,” said Espen Erlingsen, Head of Upstream Research, Rystad Energy.

“This challenges the economic feasibility of some new projects, but certain segments, including offshore and tight oil, continue to offer competitive costs, ensuring supply can still be brought online to meet future demand.”

While investments in US tight oil are expected to slow and US oil production is set to grow at a slower pace this year, investments in the offshore sector are on the rise and are seen increasing by around 5 percent in 2025, Erlingsen said in August last year.

Offshore – and the deepwater sector in particular – was heavily affected by the growth of tight oil in the last decade. Total upstream offshore investments fell from as much as $340 billion in 2014 to just $140 billion in 2021, following which they began to rise again, Rystad Energy’s Erlingsen noted.

The combination of high oil prices, improved economics for offshore projects, and lower tight oil growth were the key drivers for this development.

Rystad Energy estimates total offshore investments will reach almost $250 billion in 2025. This means that the offshore sector will most likely be the source that will drive the growth in oil production for the rest of this decade.

Subsea Spending Splurge

As a result, the global subsea market segment is poised to experience a significant influx of capital in the coming years, according to a separate analysis by Rystad Energy.

The subsea market includes players involved in production and processing systems such as subsea umbilical risers and flowlines (SURF), trees, wellheads, manifolds and other components.

Driven by rising operator expenditure on equipment and installation services, Rystad Energy forecasts a 10-percent annual compound growth rate (CAGR) in subsea spending from 2024 to 2027, with total spending anticipated to exceed $42 billion by the end of this period.

Investment activity has been particularly robust recently in regions such as South America and Europe, where major projects are making significant progress and attracting new investment.

Brazil remains a key market for subsea spending, thanks to its vast pre-salt reserves, driving strong demand for subsea equipment and SURF.

In Europe, Norway is seeing a rebound in activity, driven by favourable market conditions and technological advancements such as Subsea Hydraulic Power Unit which is cost-efficient and replaces 100 tons of deck equipment, and SWIFT™, a remotely operated tubing hanger tool which enables umbilicalless operations, reducing the need for heavy topside equipment, Rystad Energy said.

Cumulative subsea spending is estimated to have reached $32 billion by the end of 2024, up by 6.5 percent compared to the prior year.

This growth was driven by strong activity across services, equipment, and SURF, on the back of significant investment in deep and ultra-deepwater projects, Rystad Energy’s analysts reckon.

The subsea sector is also expanding beyond traditional oil and gas applications, the intelligence company said.

“The push for carbon capture and storage (CCS) is creating new opportunities for suppliers and spurring research and development in this emerging market,” Rystad Energy noted.

“Consequently, suppliers are leading the way in developing more efficient subsea production systems, which are set to see broader adoption.”

Sanwari Mahajan, Analyst, Supply Chain Research, Rystad Energy, commented,

“Looking ahead, we anticipate steady growth in the subsea sector, fueled by advancements in deepwater exploration and carbon capture and storage (CCS). This recovery highlights the industry’s resilience and suggests a promising trajectory of consistent progress.”

Subsea spending is set to be dominated by deepwater developments which are expected to account for 45 percent of the market from 2024 to 2028. Significant greenfield projects include Barracuda Revitalization in Brazil, Johan Castberg and Breidablikk in Norway,

and Golfinho in Mozambique. Key brownfield initiatives include Balder Future, Gullfaks South, and Schiehallion in Norway and the UK.

Ultra-deepwater projects, driven by major floating production, storage and offloading (FPSO) initiatives in Brazil and Guyana, are projected to capture 35 percent of the subsea market. South America is expected to lead globally with 500 subsea tree installations over the next five years. Upcoming ultradeepwater greenfield projects (beyond 1,500 meters) include Yellowtail, Tilapia, and Redtail in Guyana, alongside Buzios VIII, Buzios IX, Sepia, and Atapu in Brazil. Notable brownfield projects are Trion in Mexico, Egina in Nigeria, and Argos (Mad Dog Phase 2) in the US.

Brazil’s state energy giant Petrobras remains a dominant operator in the subsea sector, particularly in South America, where it has heavily invested in pre-salt developments.

In Europe, Equinor and Aker BP are notable for their extensive subsea portfolios, with significant tieback projects on the Norwegian Continental Shelf underscoring their strategic importance, Rystad Energy said.

In the US, the Europe-based supermajors Shell and BP lead with substantial investments in deepwater and ultra-deepwater exploration and production, while France’s TotalEnergies holds a strong position in Africa, especially in Angola and Nigeria.

Giant DiscoveriesUltra-Deepwater Revitalise Oil and Gas Exploration

Recent huge discoveries in ultra-deepwater offshore Guyana and Namibia could be the beginning of a new upswing in oil and gas exploration, energy consultancy Wood Mackenzie said in December.

Exploration has thrived in recent years and is making money, according to WoodMac’s analysts. Full-cycle returns have been consistently in double digits every year since 2015, averaging 15 percent, showed the consultancy’s analysis assuming an industry planning price of $65 per barrel Brent long term.

The recent discoveries offshore Namibia have sparked an exploration frenzy in the basin, but large international companies may have to go further and explore both sides of the southern Atlantic, according to Wood Mackenzie.

UK Underwater Industry Needs Project Certainty

In mature regions such as the UK, the underwater industry has grown in recent years, but it needs project certainty to thrive, new research from Global Underwater Hub (GUH) revealed in December.

The UK’s underwater industry has grown from £8 billion to £9.2 billion and currently supports over 51,000 jobs, GUH said.

The industry has both the capacity and capability to accelerate the global energy transition but only if project certainty is secured, according to the research.

The UK’s companies assess more positively the supply chain capacity and market prospects, especially in offshore energy, according to the 2024 Business Survey from the leading trade and development body for the UK’s underwater industry.

However, confidence in whether or when projects will be delivered has declined and 62 percent believe that project timelines will be missed.

“Our world class underwater supply chain rightly sees itself as having the necessary, leading capability to harness the opportunities across all its markets, particularly in offshore energy,” commented Neil Gordon, GUH chief executive.

“It is closing the gap towards having the necessary capacity to meet demand but does not have sufficient confidence in project timelines and returns to trigger the necessary investment.”

Continued Gordon,

“Aligned policy, timely consenting, sensible financing, concrete project timelines and clear supply chain investment are imperative to move projects from the drawing board to the seabed.” 

Advancing Integrity Management Through GDi Digital Solutions

At the end of 2024, GDi has been awarded with a first of its kind Integrity Management Support Services Contract with an operator in the UKCS.

The awarded contract encompasses comprehensive asset integrity management services across critical offshore infrastructure, with a primary focus on improving personnel safety, operational efficiency and minimising risk through the use of technology and innovation of GDi’s Vision software. GDi’s scope of work includes the integrity management and offshore inspection execution through provision of Offshore Inspection Engineers on various asset configurations.

Since its inception in 2016, GDi has been an emerging leader in asset integrity management, with a mission to redefine industry standards through innovation, expertise, and a relentless focus on delivering value. Founded on a foundation of technical excellence and a forward-thinking mindset, GDi has positioned itself as the primary solution driven choice for asset integrity management.

This contract represents a significant step in our strategic vision to become a leading force in asset integrity management across the UKCS and beyond. Our approach combines deep industry knowledge, highly skilled personnel, and advanced technologies to deliver safer, smarter, and more cost-effective asset management solutions.

Niall Shanks GDi Integrity Operations Manager

The service will leverage advanced inspection methodologies, and AI-enhanced analytics, to provide actionable insights. These insights will empower our client to make informed decisions on integrity priorities, resource allocation, and risk management strategies.

Through this partnership, GDi will contribute not only to enhanced operational performance but also to sustainability goals by optimising resource utilisation and reducing environmental impact. The integration of technology and innovation into each stage of the integrity management process will redefine efficiency and reliability in offshore operations.

Transforming the Integrity Landscape

With evolving challenges, including aging infrastructure, regulatory compliance pressures, and the need for operational efficiency in a competitive environment, GDi recognise that traditional approaches to asset integrity management are no longer sufficient to address these challenges effectively. GDi will look to harness their creative and innovative culture to provide valuable improvements to the integrity management contract.

GDi Integrity Management Workflow

GDi’s 3D asset visualisation and management solution – Vision, brings asset integrity management into a new era of clarity, precision, and efficiency. By creating highresolution, detailed digital representations of offshore assets, GDi enables engineers, inspectors, and decision-makers to visualise and interact with complex structures in a virtual environment.

These 3D models are not just static images—they are dynamic tools that can integrate live data from sensors, historical inspection results, and predictive analytics. This enables clients to simulate different operational scenarios, assess the impact of various maintenance strategies, and plan interventions with unparalleled accuracy.

The benefits of GDi’s Vision solution for integrity management include:

• Remote Inspections: One of the most transformative applications of Vision technology is the ability to conduct desktop inspections remotely, eliminating the need for engineers and inspectors to be physically present offshore. By leveraging highly detailed, accurate, and interactive digital twins of offshore assets, inspections and assessments can be performed from onshore offices, providing significant benefits in terms of safety, cost savings, and operational efficiency.

• Enhanced collaborations across teams: With digital twins accessible from anywhere, collaboration between onshore and offshore teams becomes seamless. Engineers, asset managers, and technical specialists can work together on the same model, sharing observations, annotations, and recommendations in real time. This collaborative approach accelerates decisionmaking, reduces communication errors, and ensures all stakeholders are aligned on inspection outcomes and next steps.

• Enhanced Risk Assessment: By leveraging 3D models, GDi enables clients to conduct in-depth risk assessments with pinpoint accuracy. The detailed visual representation of asset components allows for precise identification of structural vulnerabilities, corrosion hotspots, and areas of material fatigue. Through these virtual assessments, engineers can simulate various environmental and operational stress scenarios to predict potential points of failure before they manifest in the physical asset. This proactive insight reduces the chances of costly unplanned shutdowns and catastrophic failures.

• Improved Maintenance Planning: Traditional maintenance planning often relies on incomplete or outdated asset data, leading to inefficiencies and costly delays. GDi’s 3D models provide real-time, accurate information that enables clients to optimise maintenance schedules and resource allocation. Engineers can virtually “walk

through” assets to identify key intervention points, simulate repair procedures, and ensure that every task is planned with precision. This reduces downtime, minimises operational disruption, and ensures maintenance activities are targeted where they are most needed.

• Cost Efficiency: One of the most significant advantages of GDi’s 3D modeling technology lies in its ability to drive cost efficiency across the asset lifecycle. By eliminating uncertainties in maintenance planning and reducing the frequency of unnecessary inspections, clients can optimize both operational and financial resources. Furthermore, the technology reduces the need for costly physical surveys and scaffolding for manual inspections, resulting in significant cost savings over time.

Through the adoption of this technology, the result is a transformative integrity management strategy that minimises unplanned downtime, reduces costs, and enhances the overall safety and reliability of offshore operations.

At GDi, we understand that success in asset integrity management extends beyond delivering services—it requires building enduring partnerships based on trust, collaboration, and mutual goals. Our client-centric approach prioritises clear communication, transparency, and alignment with our clients’ strategic objectives.

We view each project not merely as a contract but as an opportunity to demonstrate our commitment to long-term value creation. Our team works closely with clients to tailor solutions that address their specific challenges, operational environments, and business goals.

Looking to the future, GDi remains committed to continuous improvement and technological advancement. With innovation at the core, efforts are directed toward exploring new technologies, enhancing existing solutions, and identifying opportunities to address emerging challenges in the field of asset integrity management.

This landmark contract signifies more than just a business achievement—it represents GDi’s commitment to redefining asset integrity management through technology, innovation, and expertise. As we embark on this transformative journey with our client, we remain focused on delivering solutions that are not only efficient and reliable but also contribute to a safer, smarter, and more sustainable offshore energy sector.

The recent acquisition by Oceaneering International, Inc. positions GDi to leverage Oceaneering’s global footprint and network of ready-to-mobilise personnel to provide scalability and boost expansion across new regions. With additional engineering expertise, we can drive innovation and expansion in the asset integrity management sector. GDi is well-positioned to accelerate their technology development and market penetration, paving the way for innovation and delivering exceptional value to our clients. 

Mud Vacuums & Pressure Washers

Performance You Can Trust

Nemesis Equipment delivers cutting-edge industrial solutions, including pressure washers, pumps, and solids-handling systems. As the official agent for Solidsvac, we also provide industry-leading vacuumloading solids pumps, renowned for their robust construction and efficiency.

From high-pressure cleaning to slurry management, our equipment is built to perform in the toughest environments, ensuring reliability and reduced downtime. Experience innovation and exceptional service with Nemesis Equipment.

Maximising Production through Advanced Cleaning Technologies

Leonard Hamill, Pipetech’s Operations Director

The global energy landscape is undergoing a profound transformation, presenting challenges and opportunities for the UK oil and gas sector.

Recent UK budget announcements have underscored uncertainties surrounding future drilling campaigns, driving operators to focus on extending the life of existing infrastructure. This strategic pivot reflects a broader industry trend prioritising operational efficiency and resource optimisation amid economic, regulatory, and environmental pressures. Ensuring asset integrity and maintaining efficiency have never been more critical.

Tackling the Persistent Challenge of Scale

Naturally occurring deposits such as scale and wax, have been a long-standing issue across the energy industry, clogging manifolds, and pipelines, reducing flow efficiency, and compromising operational performance. Left unaddressed, these issues can lead to costly production downtime.

Historically, operators have relied on chemical and mechanical methods to tackle these challenges. However, these traditional approaches are increasingly scrutinised for inefficiencies and environmental impact. Chemical treatments are often hazardous and corrosive, while mechanical tools struggle with complex internal geometries, leading to incomplete cleaning. As sustainability becomes a priority, the demand for innovative, eco-friendly solutions has intensified. Investing in innovative technologies is now crucial to maximise the value of existing assets, navigate market uncertainties, and align with broader sustainability goals.

Revolutionising Subsea Cleaning

As a subsidiary of Ramco Pipetech Holdings Limited (RPHL), Pipetech has established itself as a leader in delivering innovative flow remediation solutions across diverse applications, ranging from topside and subsea oil and gas assets to industrial power plants and refineries. By focusing on customer needs and advanced technologies, Pipetech ensures rapid mobilisation, minimal downtime, and maximum flow efficiency.

Among its innovations, the Deep Water Cleaning System (DWCS) addresses the unique challenges of unpiggable and complex pipeline systems, setting a new standard for subsea cleaning operations. The DWCS is the world’s first subsea-deployed, patented manifold, tree, and pipeline remediation cleaning system. Utilising high-pressure water, it removes deposits such as scale and wax with unmatched precision, restoring full flow efficiency to operating systems.

Key benefits include:

• Precise Deployment: A remotely operated system which deploys a specialist nozzle at a steady rate, ensuring consistent cleaning and minimising risks compared to manual diver-controlled cleaning systems.

• Adaptability: Designed for unpiggable pipelines, it navigates dimensional and directional changes, ensuring thorough network cleaning.

• Circumferential Tracking: Its precise rotational control and innovative nozzle design self-adjusts to diameter changes, achieving complete circumferential cleaning, with the ability to remove any naturally forming scale, including full blockages, creating a back to bare internal finish.

Operational Excellence

The DWCS enables remote cleaning operations, significantly reducing time and resource requirements. Its compact design integrates topside and subsea equipment for seamless deployment. A high-pressure water supply from topside is routed through a large bore downline to the ROV or diver operated DWCS.

With a secure foundation established through a subsea guide frame or bespoke base, the plug and play system ensures precise and efficient cleaning leading to reduced downtime and enhanced operational efficiency. By offering a sustainable alternative to traditional methods, the DWCS exemplifies Pipetech’s commitment to innovation and environmental management.

Shaping the Future of Flow Assurance

Complementing Pipetech’s DWCS and other established product lines, the company’s latest innovation, Downhole Scale Remediation (DSR) technology, addresses scale challenges within any wellbore, including subsea. This patented system uses rotational high-pressure water-jetting to remove stubborn scale deposits, restoring wellbore surfaces back to bare metal and maintaining production efficiency.

The DSR adapts to varying wellbore inner diameters and scale types, ensuring precise cleaning of critical areas like safety valves and side pocket mandrels. Unlike chemical treatments, it minimises environmental impact while delivering superior performance. Together, the DWCS and DSR provide a comprehensive suite of solutions for the evolving oil and gas industry.

In a rapidly evolving energy landscape, advancements like Pipetech’s DWCS and DSR demonstrate how technological innovation drives operational excellence and environmental responsibility. By offering sustainable and efficient cleaning solutions, Pipetech empowers operators to extend life, maximise production, and align with future energy goals. 

Headquartered in Perth, Australia since 2017, our growth and advisory services help organisations to design and execute growth plans, develop capable leadership teams and deliver exceptional outcomes for shareholders. .

Our international expansion offering has been designed speciﬁcally for UK businesses looking to establish themselves in Australia.

We have a proven track record of supporting UK companies with their entry into the local market, allowing them to capitalise on growth opportunities in the energy, renewables and decommissioning sectors across the Asia Paciﬁc region.

Talk to our team to ﬁnd out how we can help you unlock growth opportunities and Unveil your potential:

 Business structuring  Local regulatory compliance

Growth & business development services

Visa, sponsorship & migration solutions

Import, storage & transport solutions

Banking & funding partners

Established local supply chains

Performance Through Service

Total Engineered Solutions: We specialise in hydraulic, electrical, and mechanical systems, providing comprehensive services include design, manufacturing, specialist onsite services, hot oil flushing, instrumentation pipework and comprehensive equipment refurbishment.

Our mission is to deliver seamless, end-to-end support for all engineering requirements. We proudly serve a diverse range of industries, including Subsea, Oil & Energy, Decommissioning, Drilling, and Renewables.

Our expertise ensures innovative and reliable solutions tailored to meet the unique challenges of these sectors.

Serving the subsea sector

We have established a strong relationship with the Subsea sector, supporting a wide range of projects, including:

• Design, Manufacture, and Installation of critical components

• Rental of Powerpacks and Control Stations

• Complete HPUs for Marine Vessel Handling Operations

• Marine Crane Support

• Saturation Diving Bell Handling Systems

• ROV Launch and Recovery Systems

• Special linear actuators & cylinders

Our team provides expertise across mechanical, electrical, and hydraulic systems. We specialise in critical path projects, offering dedicated 24/7 support both in our workshops and onsite to meet our clients’ demanding schedules.

Equipment refurbishment

We have developed a comprehensive and market leading range of solutions to meet the growing demand for efficient and effective refurbishment and repair of hydraulic components and systems within the subsea sector.

Our experience in all types of hydraulic, mechanical and electrical system refurbishment from individual components found in systems i.e. pumps, motors, control manifolds, cylinders and accumulators. To complete units for tooling and LARS systems for ROV and diver intervention, HPU’s, winches and cranes for the material handling industries.

Refurbishment costs and quality is critical and PTS work closely with the client from the initial assessment through to final testing and certification of the refurbished component to ensure effective delivery of a certified item.

Our service personnel are available to travel locally, internationally onshore & offshore to deliver our assistance to our clients.

Track Record

This is an example of a project we are proud of that demonstrates our commitment to the Subsea sector.

LARS (Launch and Recovery System) UPGRADE

Refurbish and upgrade the operation of an obsolete system to meet a new requirement.

Challenge

• In a tight timeline, complete a refurbishment of a ROV LARS winch

• Add a simplified remote-control function

• Manufacture a new HPU for its operation Solution

• Complete refurbishment of mechanical components

• Hew hydraulic drive fitted

• DCV with manual/electrical control

• New design of a compact HPU from stock components

Outcome

• Complete Frame re-configuration and design

• Single larger local HPU and simplified local/PLC control station for operation.

• New electrical control c/w remote control valve module for assembly function

• Delivered on time and within budget.

Summary

At PTS Services, we uphold our mantra: “Performance Through Service”

With a team of over 15 experienced technicians specialising in hydraulics, electrical, and mechanical disciplines and a dedicated engineering department, we are backed by an extensive network of authorized distributorships and a large workshop and yard facility. This positions us perfectly to support the industry. 

Subsea Supplies has established itself as a trusted international supplier of ROV, AUV, oil & gas, oceanographic, and defence equipment. As the largest global distributor for the Burton Subsea connector range, we are also certified to manufacture Burton neoprene cable and connector assemblies to Eaton standards.

Elementz: Staying ahead of the curve in subsea asset integrity software

In a modern, integrated energy portfolio, maintaining subsea integrity has never been more important to uphold existing infrastructure and drive forward new energy developments.

As the industry stands poised for transformative advancements, staying ahead of the curve sits is crucial for a sustainable and resilient energy future.

That’s where you’ll find Elementz. We always stay ahead of the curve and our team continually identifies key trends, technological breakthroughs, and challenges that will shape the future of subsea asset integrity software. The prize of transforming as part of a wider digital eco-system is significant with the potential to reduce operational costs by over 40% but this means an evolving role for the Subsea Integrity Engineer who now sits at the forefront of adopting, adapting and integrating advanced technologies to modernise and optimise workflows – but they are faced with barriers and challenges in data, integration, and standardisation.

Against this backdrop, Elementz was created in 2024 and is 100% dedicated to delivering the right solutions in the right places at the right times, tackling these challenges head on. Elementz enhances the speed and quality of the entire integrity cycle by prioritising the user, leveraging their expertise and delivering an offering that seamlessly integrates into a broader digital ecosystem, driving efficiency in subsea operations and solving real problems for customers.

Our principles prioritise the need to break away from traditional, incumbent practices. By focusing on industry challenges, ensuring continuous integration, and creating openness within the overall subsea workflow, we stand alone in developing solutions that are effective, and transformative.

Central to that is looking ahead to see, understand and react to how our industry is evolving and, in 2025, that will include a

rapid transition by operators from siloed software solutions to unified, interoperable ecosystems. These digital ecosystems will provide a single, comprehensive view of operations, breaking down barriers between departments and technologies. They will drive efficiency, reduce costs, and improve decision-making by providing trusted, actionable insights. By laying the foundation for adopting and adapting to more complex twin-enabled and AI-powered operations, the ecosystems will foster a culture of collaboration and innovation.

Additionally, SaaS providers that generate valuable data will evolve by incorporating AI and other advanced plug-ins. This will empower operators to customise solutions to meet specific workflows and integration requirements, moving beyond a one-size-fitsall approach.

AI will disrupt traditional SaaS models by enabling automation and personalisation. This will lower costs, increase efficiency, and make solutions more adaptable. Operators will prioritise systems that allow leveraging of core data for tailored workflows and decisionmaking processes.

As AI and analytics dominate, data engineers will become the backbone of operational success. These professionals will design and maintain the robust data infrastructure required to support integrated digital ecosystems and advanced systems. Without clean, organised, and accessible data, AI and other advanced technologies cannot function effectively. Data engineers will ensure seamless data flows, enabling

organisations to scale their digital operations and make smarter, faster decisions.

Marine robotics and autonomous systems will become the standard for maintenance, inspection, and monitoring activities, revolutionising how the subsea industry operates.

The benefits are undeniable: these technologies are less costly, less hazardous, more flexible, and more efficient. This revolution will be powered by open, collaborative efforts between key technology and software providers.

Traditional operations teams will evolve to include roles like digital twin specialists, autonomous systems operators, and sustainability managers. These teams will rapidly adopt and adapt advanced technologies rather than relying on manual, field-based processes. These new roles will be essential for maintaining modern subsea portfolios. By improving efficiency, reducing risk, and aligning operations with sustainability goals, these teams will ensure operators remain competitive in a dynamic and ever-changing energy environment.

We are ready for a transformative year in the subsea industry. The landscape is shifting towards a smarter, more efficient future with the rise of AI, unified digital ecosystems and new operational roles. At Elementz, we’re proud to be at the forefront of these changes, enabling our clients to adapt, innovate, and thrive.

So, if you’re wondering how to find us, look for the curve and we’ll be just ahead of it. Come and join us. 

Jason Brown, Elementz CEO

Be V-LIFE readyprioritising prevention over intervention

In the demanding world of subsea operations, time is luxury. Operators face complex challenges alongside critical cables degradation. Water ingress and falling insulation resistance (IR) will halt production, threatening reliability, safety and profits.

Can we rewrite the narrative? What if operators anticipated and prevented faults over being reactive? Viper Innovations believes in a smart approach, one where readiness and resilience are within every system to proactively prepare for challenges.

With our advanced line insulation monitor (LIM), V-LIM, or subsea alternative V-SLIM, already installed, V-LIFE can be activated instantly, ‘healing’ low IR in cables and restoring system health before failure. This is the essence of being V-LIFE ready.

Why wait for a crisis?

Existing monitoring solutions allow only a reactionary response to cable faults: identify an issue, decide if the IR warrants attention, then fix it. This approach comes with the higher cost of unplanned downtime and last-minute intervention. There’s a narrow intervention window, depending on how low IR levels have dropped and when Viper Innovations is engaged. By the time IR reaches critical levels, the damage may be done.

With Intelligence Installed, Viper Innovations’ V-LIFE technology empowers operators to:

• Prevent faults before they occur

• Maintain healthy IR levels and avoid costly repairs

• Actively restore compromised cables, extending lifespans and safeguarding production

An advanced LIM in partnership with an active healing solution enables proactive maintenance and transforms how operators think about reliability.

Laying the foundation with monitoring

Underpinning this approach is V-LIM, Viper Innovations’ advanced precision monitoring technology that delivers:

• Real-time IR measurement, ensuring full system health visibility

• Early detection of faults, ahead of reaching critical thresholds, unlike traditional IMDs

• Unparalleled accuracy, differentiating V-LIM from competing integrity monitors

Should IR fall to critical levels, there’s no option for V-LIFE recovery unless the legacy LIM is replaced with V-LIM. That’s why installing V-LIM from the outset is recommended, ensuring systems are V-LIFE activation ready.

V-LIM2 takes these capabilities further. Designed for the energy sector, it delivers:

• Greater precision from enhanced IR monitoring ranges

• Power monitoring capabilities and insights

• An intuitive interface making data easier to interpret

For greenfield projects or brownfield assets, V-LIM2 meets the industry’s evolving needs. Combined with PlatformVi, Viper Innovations’ intuitive data platform, operators can monitor trends, identify risks early, and make informed decisions. Installation is all topside with no subsea intervention. For subsea applications, V-SLIM extends system health visibility downstream of subsea transformers. V-SLIM solutions are used for monitoring alongside being V-LIFE enabled, providing a suite of system health solutions—Intelligence Installed.

A holistic solution from monitoring to maintenance

Viper Innovations delivers a suite of seamless solutions to address the complete lifecycle of subsea cables:

• V-LIM: Precise monitoring and visibility via topside hardware

• V-LIM2: A future-ready version with advanced features

• V-SLIM: Subsea solution ensuring cables past subsea transformers are monitored

• V-LIFE: The only solution offering both active fault prevention and healing for cables with low IR

V-LIM, V-LIM2 and V-SLIM are essential V-LIFE enablers, with PlatformVi providing vital system health insights. This ecosystem gives operators unparalleled control, reliability and security when protecting new installations or extending infrastructure life. Intelligence Installed ensures optimal performance and long-term system health.

The power of proactivity

Timing and technology drive success in subsea operations. Knowing when to act can make the difference between uninterrupted production and costly downtime. With V-LIFE, operators make smarter decisions based on accurate data and actionable insights.

V-LIFE is easy to:

1. Install V-LIM, V-LIM2, or V-SLIM: for realtime system monitoring of topside and subsea applications

2. Use PlatformVi: accessing detailed insights, tracking trends and acting quickly

3. Activate V-LIFE: active-healing technology restoring cable integrity and extending lifespan

Ideal for existing systems and new installations, V-LIM can be retrofitted to replace older LIMs. The V-LIM portable solution provides greater flexibility for different operational needs. Additionally, the V-SLIM Eurocard and V-SLIM canister variants are for subsea applications.

Why act now?

Delaying installation increases risks that Viper Innovations’ technology helps you avoid. By being V-LIFE ready, operators:

• Save costs: Mitigate against production loss, unplanned downtime and emergency intervention

• Increase reliability: Maintain uninterrupted production

• Enhance safety: Protect people and assets

Being V-LIFE ready is a strategy to adopt technology that safeguards operations for long-term success. V-LIFE has 12+ years of field-tested performance, 500+ years of operation, is trusted by 40+ global operators and is exported to 20+ countries across six continents. By choosing V-LIFE, you’re investing in the future of your assets.

The future of subsea

As the industry evolves, operators need solutions that evolve with it. Viper Innovations’ approach prioritises prevention over reaction. Join operators worldwide who are protecting supply and assets with Intelligence Installed. Don’t let faults escalate into operation-halting failure. Be V-LIFE ready.

As assets age, cables degrade, and failures happen. Low insulation resistance caused by water ingress is inevitable, compromising production and safety...but you can mitigate the risk. The power is at your fingertips.

Simply install V-LIM today for enhanced monitoring; with increased visibility of the health of your subsea control system, there’s no need to work in the dark. You’ll also be future-proofing your system’s integrity with the ability to switch on V-LIFE, the only preventative and active ‘healing’ solution for compromised cables. It’s time to be proactive to avoid risk to production and unplanned intervention. It’s time to be v.smart and be V-LIFE ready.

For more information, visit:

www.viperinnovations.com/be-v-life-ready

Visit our stand at Subsea Expo to find out more STAND

NDT Pipeline Inspections

Underground pipelines are the hidden channels of our modern infrastructure, carrying essential resources that fuel our homes, businesses, and industries. These networks are vital for transporting water, gas, oil, and other industrial chemicals. But like any infrastructure, pipelines are susceptible to damage from corrosion, ground movement, and wear and tear. Frequent inspections are essential to guaranteeing its longevity and safety.

Non-destructive testing (NDT) offers a powerful solution that helps to assess, monitor and maintain infrastructure that is otherwise all but inaccessible- and in a way that cannot cause any damage to pipelines. NDT provides a range of testing pipeline inspections, with radiography being one of the most popular methods.

Why is it necessary to inspect pipelines?

By their very nature, pipelines transport materials that can be extremely dangerous to both humans and the environment, such as gas, oil, slurry, sewage, and chemicals. A pipeline breakdown could have disastrous results:

• Environmental contamination: leaks can release harmful substances into the soil, groundwater, and surrounding ecosystems, impacting wildlife and water resources.

• Safety hazards: gas leaks or pipeline ruptures can lead to explosions and fires, causing injuries and fatalities.

• Property damage: leaks can undermine foundations, cause sinkholes, and lead to extensive and costly repairs.

• Economic disruption: pipeline failures have the potential to interrupt vital industries and services, causing large financial losses as well as general inconvenience.

Regular NDT inspections, particularly those employing radiography, help identify potential problems before they escalate, safeguarding our communities and environment.

Inspection method: radiography

Radiographic testing employs radiographic film, combined with Computed Radiography (CR) and Digital Detector Array (DDA) technologies.

Radiographic testing (RT) involves using X-rays or gamma rays to penetrate the pipeline and create a detailed image of its internal structure. This image captured on film or a digital detector, reveals a wealth of information about the pipeline’s condition, including:

• Corrosion: locating spots where the pipe wall is thinned or pitted.

• Cracks: identifying fractures that could jeopardise the integrity of the pipeline.

• Weld defects: evaluating weld quality and spotting any flaws.

• Foreign objects: identifying blockages or debris inside the pipeline.

Advantages of radiography in pipeline inspection

Radiography offers several key advantages for pipeline inspection:

• Versatility: it can be used on a wide range of pipeline materials and diameters.

• Accuracy: it provides a highly accurate and detailed view of the pipeline’s internal condition.

• Permanent record: the pictures created act as a lasting documentation of the examination, which is useful for comparisons and analysis in the future.

• Accessibility: unlike other NDT techniques, radiography may be utilised on pipelines and in a variety of locations.

Fujifilm: advancing radiography for pipeline inspections

Fujifilm is a pioneer in NDT solutions, offering innovative radiography technologies specifically designed for pipeline inspections. Their advanced systems, including Computed Radiography (CR) and Digital Detector Array (DDA), provide inspectors with powerful tools to ensure pipeline integrity.

• Computed Radiography (CR): CR utilises reusable imaging plates that capture X-ray or gamma ray exposure. These plates are then processed in a CR reader to create high-resolution digital images. CR offers increased sensitivity and efficiency compared to traditional film radiography.

• Digital Detector Array (DDA): DDA technology employs electronic detectors that convert radiation directly into digital signals. This provides real-time imaging,

eliminating the need for film processing and enabling faster inspections. DDA also offers exceptional image quality and the ability to adjust image parameters on the fly.

CR/ DDA are beneficial for pipeline expectations for several reasons. These technologies provide results quickly and are accurate, safe with proper training, affordable and accessible, especially compared to other NDT methods.

Other significant advantages over traditional film radiography:

• Increased speed and efficiency: digital images are produced quickly, reducing inspection time and downtime.

• Enhanced image quality: digital images offer superior contrast and resolution, allowing for better defect detection.

• Improved data management: digital images can be easily stored, shared, and analysed using specialised software.

NDT pipeline inspections, particularly those utilising advanced radiography techniques, are an investment in safety, environmental protection, and economic stability. By proactively identifying and addressing potential issues, we can ensure the continued flow of essential resources through these critical underground lifelines. Fujifilm’s innovative NDT solutions allow inspectors to test and maintain the integrity of pipeline infrastructures. 

WHERE SERVICE IS THE PRODUCT

We know our customers rely on us as people, not just as a solutions provider.

At The Impulse Group, we believe that real innovation in the energy industry isn't just about products; it's about people, expertise and precision - engineering solutions to exceed expectations.

Service as a competitive edge

From flexible riser an d flowline integrity management and subsea inspection systems to our agile consulting services, we ensure you're not just keeping up with change — you're driving it.

Our engineers and experts partner with you to anticipate challenges and solve problems.

We understand the high stakes of the oil and gas industry, where performance matters more than ever. That's why our clients trust us with their projects – they value our expertise to engineer resilient solutions and provide innovation in every step.

Visualising the future of energy

Our focus is on wha t comes next — how we can continue pushing the boundaries of what's possible in oil and gas.

Our service is your competitive advantage, and our team is your partner in navigating the complexities of the energy landscape.

“Our

service isn't an afterthought – it's at the heart of everything we do.”

Mark Westerhof, BD Manager at The Impulse Group

West African Energy Summit Returns to Aberdeen for Second Edition

Following the resounding success of its inaugural event in Accra, Ghana, the West African Energy Summit (WAES) is returning for its second edition on 19-19 November 2025 in Aberdeen, Scotland.

The West Africa Energy Summit (WAES) is the premier platform that brings together the technology providers, innovators, project owners, and stakeholders driving the future of the oil & gas and energy industry. Entering its second year, WAES aims to provide an exclusive environment for meaningful exchanges between the operator side of the industry and the supply chain, specifically focusing on the technologies that enhance oil recovery and the management of asset infrastructure.

This leading international energy event will once again provide a vital platform for showcasing bankable energy projects, offshore and onshore oil and gas assets, and regional energy infrastructure projects across West Africa.

WAES is uniquely positioned as the only event of its kind dedicated to convening key stakeholders from across the West African energy value chain. Attendees will include:

• Government Ministers from West African nations

• National Oil Companies (NOCs) and Regulators

• Energy Utilities

• International business and service providers

• Global financial institutions

The summit will facilitate crucial dialogue and partnerships, driving investment decisions and accelerating the development of West Africa’s dynamic energy sector.

“West Africa holds immense energy potential, and WAES plays a crucial role in unlocking this potential by connecting project developers with the necessary capital and expertise”

Key themes for WAES 2025 will include:

• Exploration and Production: Latest developments in offshore and onshore oil and gas exploration and production.

• Energy Transition: Strategies for integrating renewable energy sources and achieving a sustainable energy mix.

• Infrastructure Development: Financing and development of critical energy infrastructure, including pipelines, power plants, and transmission networks.

• Investment Opportunities: Showcasing bankable energy projects and attracting investment into the West African energy sector.

• Regional Cooperation: Fostering collaboration between West African nations to optimize energy resource development.

As West Africa continues to position itself as a key player in the global energy landscape, WAES 2025 will provide an unparalleled opportunity for industry leaders, investors, and policymakers to engage in high-level discussions, forge strategic partnerships, and drive the future of energy in the region. 

Driving Down Costs and Increasing Efficiency

Cerulean Winds chooses Haventus to accelerate opportunities for floating offshore wind in Scotland

• The under-construction Ardersier Energy Transition Facility owned by Haventus, is selected by Cerulean, the floating wind company with 3GW under development in the Central North Sea

• Announcement marks major boost to future of offshore floating wind in Scotland, as UK floating offshore wind supply chain takes shape

• Cerulean Winds to leverage its unique experience in floating infrastructure from oil and gas sector, in particular, Alliance Contracting

Haventus, owner of the underconstruction Ardersier Energy Transition Facility, located near Inverness, Scotland, has been selected by Cerulean Winds, the lead developer of 3GW+ UK floating offshore wind, as its chosen deployment port.

Ardersier Energy Transition Facility, which has secured £400million of funding, including a £100million credit facility from the UK National Wealth Fund & Scottish National Investment Bank, will be Scotland’s largest offshore wind facility on the North Sea coast.

Cerulean’s commitment to using the facility marks a major step toward realising the UK and Scottish governments’ vision of creating a world-leading floating offshore wind (FLOW) industrial base.

By 2050, FLOW could contribute more than £47 billion to the UK economy and employ 100,000 people. Ardersier will support achieving these targets by deploying and servicing offshore wind installations, providing green jobs and establishing a UK supply chain to rival international competitors.

The Cerulean alliance’s first project will be the Aspen development, a 1GW wind farm in the Central North Sea approximately 100km from shore, that is targeting first power between 2028-29. The project is designed to enable Scotland’s supply chain and direct more than £1 billion of investment in FLOW manufacturing and service support in the country, with the Ardersier Energy Transition Facility acting as a strategic hub. This early investment will help establish the industrial foundation needed to maximise domestic economic benefits from ScotWind’s planned buildout from 2030.

Dan Jackson, Founding Director of Cerulean Winds, said: “This is an important moment for the future of the UK’s floating offshore wind industry. The UK and Scottish Governments have been very supportive, however more is needed. We must act now to capture the domestic economic benefits. If too slow, the building and maintenance of this new technology will become entrenched in established international supply chains before the bow wave of the ScotWind projects even begin, with supply chains rapidly consolidating around early-mover regions in the North Sea and Asia.”

Cerulean Winds, which has unique experience in floating infrastructure from the oil and gas sector, believes FLOW has a key role to play in addressing the Labour government’s industrial growth plan. Including, the establishment of industrial-scale port clusters and a FLOW manufacturing supply chain, and by contributing to the UK’s clean energy pipeline.

Lewis Gillies, CEO of Haventus, said: “Ardersier Energy Transition Facility will be operational by late 2025 and will be capable of supporting the deployment of multiple gigawatt-scale offshore wind projects. We are delighted that Cerulean Winds has selected Ardersier as its chosen facility, strengthening our intent to increase green jobs in Scotland, achieve economic growth and support oil and gas operators in the North Sea to rapidly decarbonise their operations.”

It is the intent that Ardersier will become the UK’s first FLOW manufacturing hub, creating hundreds of jobs and establishing a vital industrial base. From here, developers will produce and service floating foundations, anchoring this critical supply chain in Britain. The Cerulean alliance model with a clear intent to build out the Scottish supply chain creates a complete industrial ecosystem that ensures long-term economic benefits stay in Britain.

Scottish flagship offshore wind project Inch Cape reaches financial close

TheequaljointownersofInchCapeOffshoreWindFarm,ESBandRed RockRenewables,announceflagshipScottishprojecthasreached financialcloseraisingmorethan£3.5billionoffunding.

The 1,080 megawatt (MW) offshore wind farm, located in the North Sea 15 kilometres (km) off the Angus coast, will now progress into its offshore construction phase.

Inch Cape will be the first UK project to use Vestas 15.0 MW turbines and, once operational, will generate almost 5 terawatt hours (TWh) of energy each year. It will comprise 72 turbines on a mix of monopile and jacket foundations, a single offshore substation platform and two 85 km AC export cables delivering power to an onshore substation under construction at Cockenzie, East Lothian.

Terms for the £3.5 billion, which includes transmission asset costs, have now been reached with lenders comprising 22 banks.

The project will make a significant contribution to UK’s energy security and emissions reduction targets as well as to the economy through use of local suppliers. Inch Cape has, to-date, spent almost £300 million with more than 300 UK companies including environmental, technical and engineering design consultancies, civil and structural engineers, survey contractors and project management support.

Paul Lennon, Head of Offshore Wind, Hydrogen and Long-Term Storage at ESB, said: “Reaching this major milestone of financial close is a significant achievement for ESB, Red Rock Renewables and the whole project team. It is testament to the resilience, expertise and capability of the project team, project partners and both shareholders.

“Offshore wind will play a key part in the delivery of ESB’s Net Zero Strategy by 2040 and Inch Cape is an important step along that journey. We look forward to entering the main construction phase and safely delivering this project over the coming years. Inch Cape will make a significant contribution to the UK climate goals, while creating local jobs.”

Xiaomeng Chen, Red Rock Renewables CEO, added: “Reaching financial close is a monumental milestone for Inch Cape, Red Rock and our joint venture partnership with ESB. This success is a testament to the efficient design and cutting-edge technologies employed by the project, highlighting our resilience and commitment to making it one of the largest green investments in Scotland while contributing to the UK’s net zero goals.

“I’d like to congratulate and thank the project team, and everyone involved for their dedication and contribution to date. We look

forward to working with our supply chain partners to deliver a successful and safe offshore construction campaign.”

Inch Cape was first awarded planning consent in 2014 but since then has evolved to incorporate the latest technology and design. It has a 50-year lease with Crown Estate Scotland and has secured 15-year contracts with the Low Carbon Contracts Company (LCCC) through the UK Government’s Contract for Difference (CfD) auctions of 2022 and 2024.

Inch Cape Project Director John Hill said: “I am very proud for the project team – it is a great achievement to reach financial close on the Inch Cape project, which is at the forefront of technology in the offshore wind industry. The project is the largest infrastructure project currently in construction in Scotland and will deliver huge quantities of clean low-cost energy once completed in 2027.”

Construction of the onshore substation and early landfall works are now underway in Cockenzie, East Lothian, and the offshore substation jacket foundation and offshore platform are nearing completion at Smulders, Wallsend.

Offshore construction is due to begin in Q2 2025 with the start of installation of the export cables and followed by the installation of the offshore platform. First power is expected in late-2026 and with commercial operation date in 2027.

Inch Cape Offshore Wind Farm is owned by Inch Cape Offshore Wind Limited, an equal joint venture between ESB and Red Rock Renewables. 

UK Oil & Gas Advances Hydrogen Storage Project in South Dorset

UK Oil & Gas PLC has announced the completion of preliminary project design for its new underground hydrogen storage facility in South Dorset, which offers significant advantages over their previous site in Portland.

The new design allows for increased storage capacity, reduced development costs, and a strategic location closer to planned hydrogen infrastructure.

As a result, the company will focus on this project and another in East Yorkshire, discontinuing efforts at their Portland site to better align with government decarbonization targets and secure revenue support. 

As the HSE celebrates its 50th birthday, what might the future hold?

Emma

Dyson, Brodies LLP

Emma is an associate and health and safety law expert at Brodies LLP, for more information visit: brodies.com

Last year we celebrated 50 years since the Health and Safety at Work etc. Act 1974 (the 1974 Act) was introduced.

Since 1 January 2025, we can also celebrate 50 years since the creation of the Health & Safety Executive (the HSE). The 1974 Act effectively consolidated previous piecemeal legislation into a single Act applicable across all industries and encompassing a variety of employer and employee relationships, as well as the general public. It is hard to imagine the modern working world without the protection that it provides. Since 1975, the important role of enforcement of the duties imposed by the 1974 Act and educating businesses on their obligations is carried out by the HSE.

Fifty years on, the world continues to find new and innovative ways to create energy and fuel our evolving world, and as with all new technologies this comes with an increase in risk. As a result, legislation and how regulators enforce it must evolve too.

The Health and Safety Executive in action

The 1974 Act imposes an overarching duty on employers to ensure their employees’ health, safety and welfare so far as is reasonably practicable. It also protects the public from risks arising from workplace activities. On a day-to-day basis, HSE Inspectors are responsible for enforcing these duties. The powers of HSE Inspectors are therefore wideranging and important, for example, entering

premises, interviewing people, ordering certain work to cease, machinery to be stopped, or seizing documents or equipment.

Most importantly, the HSE has the power to take enforcement action if its inspectors find that a business has breached its health and safety obligations. In England and Wales that extends to directly initiating criminal prosecutions. In Scotland the HSE works with the Crown Office and Procurator Fiscal Service when it considers that criminal proceedings are justified.

The HSE provides specialist Inspectors who have in-depth knowledge of specific sectors, and the specific demands, risks and challenges that each industry sector faces, including the energy sector. As a result of having specialist regulators and the huge body of regulations that flow from it, health and safety has become a proactive, fundamental part of working life rather than a retrospective reaction to an incident. The step-change that has been made in the UK is shown by recent statistics published by the HSE which confirm that in 1974, before the inception of the Act, 651 workers were killed at work. In 2023/2024 that number had reduced to 138. That is still too high a number, but it is right that from time to time we pause and recognise the huge progress that has been made, before turning again to face the challenges ahead.

What is on the horizon for safety in the energy sector?

Of the workplace deaths the HSE reports each year, falls from height remain the most common cause. With the increasing focus on the energy transition and the growth of onshore and offshore wind as Scotland’s preferred source of clean energy, it is of no surprise that the HSE is looking closely at wind farm operations. The risk associated with wind power was highlighted in a Fatal Accident Inquiry held last year which considered an incident in 2017 involving a worker falling from the top of a wind turbine, as well as during an HSE investigation when a turbine blade came off at a wind farm in East Ayrshire.

As part of its longer 10-year strategy, the HSE is also examining work-related ill health from depression, stress and anxiety. As a result of the recent work done by the IADC and the offshore industry more generally, it is recognised that offshore working in particular, carries a higher risk given workers are away from home for long periods, working in shifts or alone and facing increased stress due to the high-risk environment and the consequences of even the smallest of mistakes.

The challenge for regulators and businesses going forward is to recognise the pace of change and ensure that both the regulatory environment and operational policies and procedures also evolve at the same pace. That will require continued collaboration between industry and regulators. There is little doubt that the energy industry and the HSE will continue to work closely to address risks created by nascent technologies. A good example of this in action is the Winlaton Hydrogen Trial in 2022 where a town was used to test the possibility of using hydrogen blended natural gas in the gas network. The HSE was consulted and approved the trial which was successful in demonstrating that hydrogen could be safely used as fuel in a domestic setting in the future.

Half a century on, the HSE continues to provide protection for all types of work and modern ways of working that probably couldn’t have been imagined at the time of its inception.

the UK and internationally. For more useful insight and details of our energy expertise visit brodies.com

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Innovation in the Energy Industry: The Subsea Revolution

The energy industry has always been at the forefront of technological advancement, adapting to an ever-changing world where energy demand is intertwined with sustainability concerns

One area in the industry that has consistently pushed boundaries is subsea energy exploration and production. Over the past few decades, innovations in subsea technology have redefined how we harness resources from the depths of the oceans, transforming these once unreachable regions into major contributors to the global energy supply. This revolution has not only boosted efficiency in marine energy extraction but also supported the transition toward clean, renewable solutions.

One of the most impactful innovations in subsea energy has been the development of remotely operated vehicles (ROVs) and autonomous underwater vehicles (AUVs). These robotic systems are designed to operate at extreme depths, collecting valuable data and performing complex tasks in environments where human divers cannot venture. Equipped with advanced imaging, mapping, and sensing technologies, ROVs and AUVs play a critical role in subsea construction, maintenance, and decommissioning operations. These robots drastically reduce risks associated with offshore exploration and development by removing the need for human involvement in dangerous conditions. Furthermore, as these vehicles become more sophisticated, their ability to inspect pipelines, identify leaks, and monitor subsea installations ensures greater efficiency and sustainability in energy production.

Subsea production systems have also undergone revolutionary changes in design and functionality over recent decades. Traditional offshore platforms are increasingly being replaced by subsea systems that operate on the seabed, streamlining production and reducing costs. Innovations such as subsea

manifolds, trees, and compressors allow for the extraction and processing of oil and gas directly on the ocean floor, decreasing the need for complex surface infrastructure. The development of subsea-to-shore solutions— where extracted resources are transported via underwater pipelines directly to onshore facilities for processing—has further reduced environmental and operational footprints. These systems are highly scalable, enabling operators to tap into fields in ultra-deep waters where surface installations were once impractical.

The digital transformation of the energy sector has extended to the subsea domain, where Big Data analytics and advanced simulation tools play an instrumental role in improving operations. Through the use of fibre-optic sensors, real-time data can be gathered from subsea installations, allowing operators to monitor the status of wells, pipelines, and machinery with unprecedented precision. Moreover, machine learning and artificial intelligence (AI) algorithms are now being deployed to analyse vast datasets collected from the seabed. These tools enable better predictive maintenance, identifying equipment failures before they occur, which not only optimises production but also prevents environmentally damaging accidents.

While oil and gas have dominated subsea energy, there is significant momentum in the development of renewable energy solutions beneath the waves. Offshore wind farms are becoming increasingly common, with floating turbines enabling the generation of power in deeper waters where fixed installations are untenable. Similarly, tidal stream and wave energy converters are emerging technologies

that harness the power of ocean currents to produce clean, reliable energy. These renewable subsea energy sources are still in their infancy compared to oil and gas, but the global push for sustainable energy solutions has accelerated their development. With governments and corporations investing heavily in ocean energy, subsea renewables are poised to become a cornerstone of the green energy transition. The subsea energy revolution has not just improved efficiency and cost-effectiveness but also advanced sustainability goals. By minimising environmental disruption and reducing the carbon intensity of operations, modern subsea technologies align with global efforts to combat climate change. Renewable energy systems are perhaps the greatest testament to the subsea industry’s contribution to sustainability. As the energy transition continues, the ability to harness clean energy from offshore sites will play a vital role in safeguarding the planet’s future while meeting society’s energy needs.

Despite these remarkable advancements, the subsea energy industry still faces hurdles. Extreme underwater conditions demand rigorous testing of equipment and technologies, and the costs of subsea operations remain high compared to landbased alternatives. Additionally, as global attention shifts to renewable energy, balancing investment between traditional hydrocarbon extraction and emerging green technologies is a key challenge. In response to these challenges, the UK government has implemented various initiatives to support these advancements, such as funding programs, grants, and collaborations with industry and academic organisations. These initiatives aim to encourage the adoption of emerging technologies and the development of novel solutions.

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

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Petrobras Extends FPSO Cidade de Angra dos Reis Charter

State-owned oil and gas major Petróleo Brasileiro S.A. (Petrobras) has extended the charter period for the floating production storage and offloading units (FPSO) Cidade de Angra dos Reis by an additional five years, until 2030.

Petrobras signed amendments to the charter and service agreements for the FPSO on behalf of the Tupi field consortium with Tupi Pilot MV 22 B.V. and Modec Serviços de Petróleo do Brasil Ltda.

In a media release, Petrobras said that the amendments aim to enable upgrades to the FPSO, which currently has a production potential exceeding 50,000 barrels per day (bpd).

“The planned improvements are intended to enhance production reliability and efficiency, maintain platform integrity, operational safety, and reduce greenhouse gas emissions. The consortium plans to decommission the unit in 2030”, Petrobras said.

The FPSO Cidade de Angra dos Reis has been operating in the Tupi field since October 2010, when it became the first high-capacity FPSO to work in the pre-salt layer of the Santos Basin, according to Petrobras.

MODEC converted the VLCC Sunrise IV into the FPSO Cidade de Angra dos Reis, a unit capable of processing up to 100,000 barrels of oil per day and 5 million cubic meters of gas. The FPSO is designed to remove hydrogen sulfide (H2S) and carbon dioxide (CO2), with the capacity to reinject CO2 downhole at 550 bar and export sales gas to shore, according to MODEC.

Petrobras said the amendments align with its 2025-2029 Business Plan and reinforce its commitment to the continuity and expansion of the Tupi field.

Equinor awards preliminary design contracts for stalled Bay du Nord project

Equinor placed the Bay du Nord project, approved by Canada in 2022, on hold for three years in 2023.

Equinor has initiated preliminary work on the Bay du Nord oil project in the Canadian province of Newfoundland and Labrador, contracting BW Offshore and Altera Infrastructure for design studies.

This move comes despite the project’s current hold status as the company assesses cost-effectiveness.

BW Offshore, based in Norway, has been tasked with a preliminary design study for a production and storage vessel for the Bay du Nord oilfield.

The company’s news release states that this work aligns with Equinor’s strategic objectives for the project.

Similarly, UK-based Altera Infrastructure has confirmed its involvement in a preliminary design contract related to a production and storage vessel. These contracts suggest progress in the project’s planning phase, despite no final decision on its commencement.

The Bay du Nord development, sanctioned by the Canadian government in 2022, was put on hold for three years by Equinor in 2023 to enhance cost efficiency. The $16bn (Nkr179.88bn) project’s future remains uncertain, but these preliminary contracts indicate ongoing interest.

Situated around 500km from St. John’s, the Bay du Nord oilfield is said to be the first deep-water oil project offshore Newfoundland and Labrador.

The field, discovered in 2013, with subsequent finds up to 2020, lies in waters approximately 1,170m deep.

Equinor plans to utilise a floating production, storage and offloading (FPSO) unit for the Bay du Nord field. This FPSO unit is considered an optimal solution for connecting adjacent discoveries and future prospects.

The Tupi consortium comprises Petrobras, with a 67.216 percent stake, Shell, with a 23.024 percent stake, Petrogal, with a 9.209 percent stake, and PPSA with a 0.551 percent stake. 

The Bay du Nord project, once operational, is set to be one of the world’s lowest-carbon projects per barrel of oil produced.  SPONSORED BY

Aker Solutions ASA: Aker Solutions signs long-term strategic partnership with Vår Energi

Aker Solutions enters a strategic partnership agreement to deliver maintenance and modification services on Vår Energi operated assets and projects on the Norwegian Continental Shelf (NCS).

The partnership also includes Honeywell and StS-ISONOR and builds on an already established collaboration model with clear incentives to work as an integrated team towards common goals.

ModuSpec secures £250,000 of UKCS wins

ModuSpec has enjoyed a strong start to 2025 after securing multiple project wins in the United Kingdom Continental Shelf (UKCS) recently, worth in excess of £250,000.

The contract awards include supporting the intake of two cyber jack-up drilling rigs and two semi-submersible drilling units, delivering a mix of customised rig intake and inspection services for existing clients based in Aberdeen.

Both jack-up drilling rigs will be engaged in plug and abandonment operations around the UKCS as fields have reached cessation of production. Each project will see a multidisciplinary team of ModuSpec surveyors attend the rigs to verify readiness for upcoming contracts with International Oil Companies (IOC).

For the semi-submersible rig projects, ModuSpec will support an IOC to verify in between well maintenance (IBWM) and deployment of a blowout preventer (BOP) onboard an ultra-deepwater and harsh environment 6th generation deepwater semisubmersible. Surveyors will ensure compliance with company rules and successful subsea testing prior to commencement of drilling.

The final semi-submersible project entails a comprehensive intake of a 3rd generation unit currently stationed quayside in a shipyard. Focus is placed on ensuring compliance with

The contract has a duration of 5 years with the option to be extended up to 11 years.

“We are proud to be a trusted and strategic partner for Vår Energi. At Aker Solutions, we believe that strong partnerships drive efficiency, foster continuous improvement, and enable a leaner project organization,” said Paal Eikeseth, executive vice president and head of Aker Solutions’ Life Cycle segment.

The strategic partnership aims to create value through joint project planning, safe and efficient execution, collaboration and shared objectives.

Vår Energi’s chief operating officer, Torger Rød, is pleased to initiate a four-party collaboration with the team:

“Aker Solutions, Honeywell and StS-ISONOR represent world-leading technical expertise

UK North Sea standards including verification against the existing Safety Case, Written Scheme of Examination and Performance Standards of the major equipment. The rig will be utilised for abandonment work in the Central North Sea.

Mark Watson, Operations Director with ModuSpec, said: “We are delighted to secure further business in the UKCS, where nearly 40 years ago ModuSpec conducted its first project. Even as the basin is ageing, our services remain key to a number of longterm clients who are engaged in development drilling and plug and abandonment activities.

“Each project we have secured is different in its own right – a reflection of our ability to listen to our client needs and provide customised solutions which are also beneficial to the rig owner. We promote collaboration during service delivery to ensure our client gains from additional value and efficiency, our key differentiator in the market.

“During Q1, we look forward to working with our clients and continuing to grow our business with $1.5m of business recently generated in North Africa and Middle East region.” 

and extensive experience in areas of strategic importance to our activities. With Vår Energi’s clear growth ambitions, a strong and longterm partnership is crucial. We are working purposefully to achieve results through close collaboration, actively utilising our partners’ core competencies. By year-end, we will increase production to around 400 thousand barrels per day, which makes us one of the world’s fastestgrowing oil and gas companies.”

Vår Energi’s operations span the entire Norwegian continental shelf with a diversified portfolio of 200 licenses and 42 producing fields.

In December 2024, Aker Solutions signed a sizeable1 frame agreement to deliver maintenance and modification services for Vår Energi’s Jotun, Balder, and Ringhorne assets in the southern Norwegian Continental Shelf (NCS). These activities are part of the partnership. 

SLB Secures Multiple Drilling Contracts for Shell’s Deepwater Assets

SLB, a leading energy technology company worldwide, has signed a string of deals with the British energy giant Shell plc to support its deepwater and ultra-deepwater assets. The energy technology firm has won major drilling contracts from Shell in the U.K. North Sea, the U.S. Gulf of Mexico and Trinidad and Tobago, among other regions.

These projects will leverage SLB’s AI-enabled digital drilling tools and technology and its extensive knowledge and experience of working in ultra-deepwater environments. By combining its expertise in these harsh and challenging environments with AI-enabled capabilities, SLB aims to enhance the costeffectiveness of drilling these wells.

The projects will be completed over the course of three years. SLB has already started work on these contracts. The contracts cover a wide range of drilling services for the efficient development of the wells. SLB will provide digital directional drilling services and hardware to optimize the drilling process.

Further, the company will use logging while drilling to obtain real-time data about subsurface conditions alongside surface logging to better understand the geological formations. The scope of the contract also includes wireline services, cementing, drilling and completion fluids, and completions. 

Navigating decommissioning rules is key to attracting North Sea investment

Liability regulation concerning offshore infrastructure can make the process seem like a financial burden

Following another year of progress towards a green energy transition, greater activity in renewables and the news of GB Energy coming to Aberdeen, there are reasons to feel cautiously optimistic about the next chapter for the North Sea.

Financial pressures remain, but the Chancellor’s Autumn Budget at least provided some clarity about the extension of the Energy Profits Levy (EPL) until 2030 – depending on oil prices – among other measures.

As we begin a new year, it is a great time to press reset on the general feeling of uncertainty that has clouded over the sector for the last couple of years.

Continuing that theme, there are huge opportunities be grasped in terms of the energy transition.

Decommissioning, in particular, is only going to be a growing focus for the sector. The scale of the task is enormous, with more than 250 of the North Sea’s 880 fixed and subsea installations earmarked for decommissioning – and more likely to follow.

Around 4,000km of subsea pipeline also needs to be removed from the seabed and a target has been set to take out 1,500km by 2030. Estimates from the North Sea Transition Authority predict a spend of £21bn over the next decade alone.

For many companies already operating in the north east, the energy transition is mostly being seen as a natural evolution and a new challenge to get stuck into. We have a workforce with decades of experience in setting up the oil and gas infrastructure that will become an invaluable pool of knowledge when it comes to removing it as part of that transition.

The best people to complete the job are already here, which puts us at a huge advantage.

However, we can’t shy away from the fact that decommissioning is often perceived as a financial burden, which may prevent traditional energy companies and supply chain businesses from remaining in the market. The complexity of the decommissioning challenge should mean many attractive and lucrative contracts up for grabs in the years to come, but, for the moment, there are still a range of considerations causing some to take a more glass-half-empty view.

Decommissioning liability rules covered in Section 29 of the UK Petroleum Act (1998) could, in some cases be a limiting factor for further investment into the market. The legislation means that past and present licensees of a particular asset can be held accountable for decommissioning work and returning the seabed to its original clean state. In practice, while the guidelines are clear in certain scenarios, there are some elements that only create further uncertainty.

For example, ‘liability in perpetuity’ has been a hot topic of discussion for well over a decade now and a strategic solution has not yet been found for any infrastructure left in situ.

What happens if a company that holds the liability for part of the decommissioning process, such as the requirement for routine environmental surveys and any subsequent remediation, ceases trading or moves all of its operations overseas?

In theory, there should always be a parent company, or another partner that the liability is transferred to, but in a worst-case scenario, the responsibility could fall to the taxpayer.

In an ideal world, some kind of sector-wide cooperative or insurance fund might exist – similar to the Offshore Pollution Liability Association – giving everyone a degree of reassurance and an emergency safety net for the future. Contributions could be structured to reflect each operator’s decommissioning exposure, allowing a mechanism to deal with unforeseen liabilities.

We may not have all the answers at hand to solve these challenges, but by working together with all the parties involved in the operation of an offshore oil and gas asset, we can create contracts and frameworks that cover all eventualities. A robust, one-size-fitsall process for decommissioning may emerge as the market matures, but in the meantime, the sector needs to collaborate and find new ways of working that can encourage, rather than prevent, future investment across all areas of the market. 

Australia’s O&G dismantling boom: specialists in high demand

The Australian government has started sounding out specialists to tackle the decommissioning of more than 200 pieces of aging oil and gas infrastructure, all set for the scrapheap this year.

The Department of Industry, Science and Resources (DISR) has issued a call for technical specialists to guide the dismantling of aging oil and gas platforms and associated infrastructure in Australian waters, with a focus on minimising environmental impact.

The move comes as Australia braces for a surge in decommissioning activity. According to the Centre of Decommissioning Australia’s (CODA) Decommissioning Forward Outlook, the initial contract period from February to July 2025 will see significant activity.

The program spans 41 platform wells, 34 subsea wells, 15 exploration and appraisal wells, 13 fixed facilities, two floating production units, 15 pipelines, 33 flowlines, 19 static umbilicals, and 34 other subsea structures.

The tender, published on January 9, 2025, outlines the need for expert advice to navigate the complexities of decommissioning under Australia’s newly tightened regulatory framework.

Regulatory reforms and industry challenges

The volume of Australia’s aging offshore oil and gas infrastructure is pushing decommissioning to the top of the government’s agenda, sparking a significant overhaul of the Offshore Petroleum and Greenhouse Gas Storage Act 2006 (OPGGS Act). Research from CODA suggests there is a combined liability of about USD $40.5 billion (including wells and facilities), with well P&A and pipeline removal accounting for the majority of estimated spend).

With so many platforms nearing the end of their operational lives, authorities are tightening the regulatory net to safeguard both taxpayers and the environment.

Liberty Industrial completes Northern Producer decommissioning with 98% material recycling rate

Liberty Industrial has successfully completed the decommissioning of the Northern Producer Floating Production Platform, achieving a 98% recycling rate.

This project, the company’s second decommissioning undertaking in the UK, took place in Kishorn, Scotland, and is notable for being the first major decommissioning project conducted in the remote region.

The work involved decontaminating, dismantling, and repurposing materials from the 11,200-tonne asset, while following stringent local and international environmental standards.

The Northern Producer, a retired floating production platform, was decommissioned in a dry dock on behalf of Qualimar Shipping Limited and Northern Offshore UK Ltd.

The project was completed with zero environmental breaches, no incidents, and no lost time, which Liberty Industrial said exemplifies its focus on safety and environmental responsibility. The high standards of work to which the project was carried out to, also saw it win Project of the Year in the Explosive Category at the 2024 World Demolition Awards.

Environmental and Recycling Achievements

Liberty Industrial’s approach centred on minimising landfill use and maximising material recovery.

By utilising a comprehensive waste management programme that comprised precise categorisation, processing, and tracking of materials to ensure efficient recycling, the project resulted in significant environmental and recycling outcomes:

Steel Recycling – Over 11,200 tonnes of steel were recycled, contributing significantly to the circular economy.

Equipment Repurposing – Five Solar Turbines gas engines, two gearboxes, and various electrical instruments were salvaged and sold for global reuse.

Marine Waste as Fertiliser – 42 tonnes of marine growth were treated by Keenan Recycling to create nutrient-rich fertiliser, which was distributed for agricultural use in the local community.

Lifeboats Resale – Four lifeboats were sold to local buyers, repurposed for recreational purposes.

Rock Blanket Reuse – A 4,500-tonne rock blanket used to protect the dock floor was preserved for future decommissioning projects.

Heritage Contributions – Marine artifacts from the platform were donated to a heritage site.

Ballast Water Treatment – More than 1,300 cubic metres of ballast water was safely treated and discharged following regulatory standards.

Collaboration with Local and International Entities

The project was executed in partnership with several organisations, including Solar Turbines, European Metal Recycling, 4D Controls, and Keenan Recycling, as well with the support of the Scottish Environmental Protection Agency. Local community members also played a role by purchasing lifeboats and other items for reuse.

Liberty Industrial’s Director, Clinton Dick, said: “At Liberty Industrial, we aim not only to deliver the best environmental outcomes on every project but also to provide transparency for our clients to support their own sustainability goals.

“The recycling program aims to recirculate materials back into the supply chain. This project exemplifies our values and showcases our dedication to decommissioning leadership for the oil and gas industry.” 

Petronas to decommission $1.5bn Sabah Sarawak gas pipeline in Malaysia

Malaysia’s state energy firm, Petronas, announced in its activity outlook report that it will proceed with the decommissioning of the Sabah-Sarawak gas pipeline.

The 500 km natural gas pipeline in Malaysia connects Kimanis in Sabah to Bintulu in Sarawak and has been operational since early 2014.

For the next three years, Petronas’ decommissioning plans include the plugging and abandonment of about 153 wells and the abandonment of about 37 offshore facilities, according to the report.

In November last year, the company lifted the force majeure on gas supply to the Dua Malaysia LNG terminal after it was shut in 2022 following a leak in the Sabah-Sarawak pipeline. 

KEY

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Supporting Subsea Travel

Zara Higgins, General Manager – ATPI Scotland

Despite market changes, the North-east of Scotland remains an active hub for the global energy industry. From Aberdeen and the surrounding area’s energy community, industry pioneers and leaders have laid the foundations for operations locally and internationally.

Regardless of the changes to energy security, Scottish energy – and the subsea sector – has a future, whether through offshore wind or tidal, nuclear or geothermal energy, or emerging carbon capture projects. The continued interest that global organisations have in the region reflects this. Over the coming years, Scotland-based businesses will continue to deliver their proven expertise and resources to benefit the global energy market, while international operators will explore opportunities within the region.

 With varying and stringent health and safety regulations changing per region, considerations for volatile and high-risk destinations and the harsh environments associated with remote locations are unavoidable.

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Accessibility is crucial in developing new relationships and partnerships. We must ensure that leaders and workforces coming to Scotland to share their knowledge can arrive with ease. Likewise, we want to be able to share our energy expertise with the wider world.

Travel management and the insight to navigate industry travel requirements are critical.

Challenges of Travel for Subsea Operators

Energy travel requirements, including those for subsea projects, present businesses with unique challenges given the need to arrange travel for offshore rigs, oil platforms, and remote exploration sites. As travel is one of the more significant expenditures a company accounts for after staff salaries, it is essential to get it right. Not only is it costly to navigate any travel missteps, but the potential knockon impact is also significant. A business will quickly experience the consequences of a delayed or misplaced workforce.

For journeys that require meticulous planning, extensive risk management, and a deep understanding of the logistical complexities involved, companies need a travel management solution that prioritises efficiency, safety, and cost control.

When heading offshore, the most common intricacies include:

 Complex itineraries that feature coordinating multiple flights, helicopter transfers, and sea transport - all of which require precision and flexibility.

 Crew changes and rotations to ensure smooth handovers and maintain operational efficiency while meeting legal requirements. Not to mention that managing crew rotations is a timely and costly logistical challenge.

Managing travel to offshore rigs and remote locations in the energy sector requires specialised expertise and meticulous planning. External travel management support can help streamline your operations and ensure that you can navigate the complex and bespoke logistical challenges of the energy industry. This is particularly critical for the crews and companies working offshore and managing subsea projects in remote locations where operations need to run like clockwork.

By trusting the specialised services offered by travel management companies (TMC) like ATPI, you are acquiring a deeper understanding of travel intricacies. An established energy and offshore travel management background means you are utilising solutions specifically developed and tailored to the industry’s needs, including the latest state-of-the-art technologies and platforms. At ATPI, platforms such as CrewHub and TravelHub help traverse the volatile nature of the oil and gas industries to improve efficiency, ensure safety, and control costs, empowering those within energy to enhance their approach to travel.

From managing complex crew rotations to ensuring compliance with safety protocols, ATPI provides a comprehensive suite of services that modernise travel coordination and reduce costs. Some of the advantages ATPI provides for offshore travel include:

 Optimising Travel Routes: We plan efficient travel routes to minimise costs and reduce the environmental impact of travel.

 Travel Management Systems: Our systems provide real-time data, streamline booking processes, and ensure seamless coordination of travel plans.

 Mobile Solutions: Our mobile apps allow travellers to manage their itineraries, receive updates, and access support services on the go.

To ensure the offshore workforce receives comprehensive support from door to deck, consider partnering with a TMC.

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