Issue 94 - Asset Integrity

GLOBAL ENERGY NEWS

ENERGY PROJECTS MAP ASSET INTEGRITY LEGAL INNOVATION CONTRACT AWARDS DECOMMISSIONING EVENTS

Welcome to the July edition of ‘OGV Energy Magazine’ where this month we are exploring the theme of ‘Asset Integrity’ which is critical to the global industry’s preservation of its production infrastructure.

A big thank you to our front cover partner Stats Group this month and you can read all about their market leading technology involved with the maintenance of process pipework on pages 4-5.

We are also delighted to welcome contributions from Three60 Group, GDi - An Oceaneering Company, CAN Group, Elementz, PTS and Tess Aberdeen.

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

Thanks as always to our corporate partners the Energy Industries Council, Leyton, Infinity-Partnerships, Elemental Energies and Archer - the Well company, Three60 Energy, Brimmond, Drager, Rotech Subsea, Stats-Group, Cegal, GDi, PTS Services, ESWL, Tess, Intervention Rentals, Vulcan Completion Products, Viper Innovations, J&S Subsea, Wellpro and Scotsbridge.

The smartest and safest

way to isolate

The maintenance of process pipework and pipelines plays a vital role in ensuring the reliability, safety, and operational efficiency of oil and gas infrastructure, which is a fundamental pillar of global energy supply.

Effective maintenance ensures the integrity of pipelines, preventing leaks, corrosion, and structural failures that could have a significant impact to people, the environment or supply of vital energy to homes and businesses.

The complexity and scale of oil and gas pipelines require sophisticated maintenance strategies. These process plants and pipelines are situated in a range of diverse environmental conditions and challenging terrains, such as urban areas, mountains, deserts, and marine locations. To meet these demands, innovative technologies and advanced methodologies are essential for maintaining the integrity of these extensive networks.

STATS Group’s industry-leading temporary pipeline isolation technologies exemplifies the sector’s commitment to innovation, safety, and efficiency in critical repair scenarios. Prioritising safe, high-integrity pipeline isolation is essential for managing the challenges of piping and pipelines operating under varying pressures, temperatures, and mediums, often in harsh conditions.

Market Leading Isolation Technology

For more than 25 years, STATS has been pushing the boundaries of pipeline isolation technology featuring leak-tight, dual elastomer seals. Clients often approach STATS to develop engineered solutions and innovative technologies to solve their complex pipeline integrity challenges. An extensive history of providing robust solutions has led to the development of many patented technologies, which are now standard products.

STATS BISEP® technology provides operators pioneering hot tap installed line stopping capabilities to enable the safe and effective repair and modification of pipeline infrastructure.

The patented BISEP provides a fail-safe double block and bleed isolation deployed through a single full bore hot tap intervention and is the only DNV Type Approved line stop tool. This verifies that the design criteria satisfy the requirements for Pipeline Isolation Plugs to provide dual sealing and isolation in accordance with; DNV-OS-F101 (Submarine Pipeline Systems) and recommended Practices; DNV-RP-F113 (Subsea Pipeline Repair) as well as in compliance with code ASME BPVC Section VIII, Division 2.

The BISEP offers significant safety advantages over traditional line stop technologies, with the hydraulically activated dual seals providing leak-tight isolation of pressurised pipelines. The dual seal isolation barrier is confirmed once each seal is independently tested with full pipeline pressure in the correct direction and the pressure between the seals is vented, creating a zero-energy zone. The zero-energy zone between the seals is monitored throughout the work scope, confirming the isolation integrity with zero leakage, a crucial factor in the energy industry where any compromise in integrity can have severe consequences.

To support hot tapping and line stopping activities, particularly in larger diameter pipelines, significant product development and investment has been made to extend STATS’ range of SureTap® hot tapping machines with the introduction of the ST1530-90 XL. Three new SureTap ST153090 XL hot tapping machines have been manufactured and distributed to key regions to meet demand. The new model supports cuts up to 60” in diameter and offers an extended reach of 180”.

STATS’ DNV type approved Remote Tecno Plug® is a piggable, remote-controlled, tetherless isolation tool. The inline plug features dual elastomer seals and taper locks providing leak-tight double block and monitored isolation, allowing systems to remain pressurised, live and operational during repair activities. The dual seal plugs feature a zero-energy zone to enable maintenance work on pressurised systems to be carried out safely and efficiently. The remote-control system provides a high degree of flexibility, suitable for onshore, topsides and subsea applications.

Energy Transition

With investment in carbon capture and storage and hydrogen accelerating, there is a growing focus on how existing pipeline infrastructure can be repurposed.

The requirement for isolation and intervention technology to isolate these critical energy pipelines safely and efficiently for repair, maintenance and modifications is increasingly important.

Supporting pipeline owners and operators’ transition to more sustainable energy, STATS double block and bleed isolation technology is already proven to provide high integrity leak-tight isolation in both 100% hydrogen and high-pressure liquid CO2 pipelines.

Emissions Reduction

As pipeline operators deal with the challenges associated with eliminating greenhouse gas emissions during pipeline maintenance and facility upgrades. STATS’ inline (Remote Tecno Plug) and hot tap installed isolation (BISEP) tools are contributing to reducing carbon emissions for their customers. Using leak-tight, double block and bleed pipeline

isolation technologies, localised repair and maintenance worksites can be safely isolated without the need to depressurise large sections of the pipeline, thereby avoiding the need to discharge significant quantities of greenhouse gases into the atmosphere. In the case of large diameter gas pipelines, this can prevent the potential discharge of thousands or tens of thousands of tons of methane emissions into the atmosphere.

STATS continues to support its customers to reduce emissions, recognising the pivotal role that natural gas is playing as the world seeks to first reduce carbon emissions ahead of a longer-term transition to more sustainable sources of energy.

Andy Norrie, Head of Sales and Business Development, Europe at STATS Group commented: “There’s a growing market awareness of the integrity of our patented equipment and the sustainability features offered by our technologies, particularly in helping reduce carbon emissions for our clients.

“There are many examples of this approach globally. In the UK, a Remote Tecno Plug was deployed to enable a 48” diameter pipeline to remain fully pressurised at 55 bar for 56 km during replacement of an insulation joint and was used instead of traditional venting or recompression operations.

“Compared to conventional pipeline recompression methods, the Tecno Plug prevented the discharge (venting) of approximately 332 tonnes of gas, equivalent to over 7,500 tonnes of CO₂ in environmental impact. This reduction is comparable to taking around 4,500 cars off UK roads for an entire year. Additionally, the installation and testing of the Tecno Plug were completed in just 24 hours, significantly faster than the weeks typically required for recompression operations.”

In Canada, STATS completed one of the industry’s first leak tight double-block and bleed isolations with the BISEP tool which achieved emission-less venting. This prevented releasing methane emissions into the atmosphere, and in one project alone is estimated that more than 1.6 million scf of methane was not vented, the equivalent of 913 metric tonnes of CO2e saved or taking 197 motor vehicles off the road in Canada for one year.

Additionally, the Remote Tecno Plug was used by TC Energy in Canada to isolate a localised section of 36” natural gas pipeline during valve replacement and hot work activities. The use of the inline isolation plug improved pipeline safety and reduced GHG emissions by 38,860 tonnes, the equivalent to taking 6,863 cars off the road for one year. This approach also shortened operational downtime of the pipeline compared to similar work.

Innovation

The evolution towards advanced solutions signifies a proactive approach to ensuring the integrity of pipeline infrastructure, emphasising the indispensable role of technology in safeguarding the energy networks that power our world.

Double block and bleed / monitored isolation tools offer a comprehensive and efficient solution for the repair and maintenance of oil and gas pipelines. The ability to perform operations without shutting down the pipeline, providing dual leak-tight seals for enhanced safety and real-time seal monitoring capabilities, position these technologies as valuable assets in the industry.

Mr Norrie concluded: “We’re excited about the future energy transition and the role STATS is playing in supporting our customers to achieve their net-zero goals and provide the highest level of safety during temporary pipeline isolation.” 

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

Editorial

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Design Jennifer McAdam Cali Gallow

Editorial Tsvetana Paraskova

COMMUNITY news

Hunting PLC Acquisition of Flexible Engineered Solutions (Group) Holdings Limited (“FES”) and Capital Allocation Policy Update

Hunting acquires FES, a leading provider of fluid transfer solutions to the offshore oil and gas and renewable energy industries, for £50 million. Hunting PLC, the precision engineering group, announced that it has completed the acquisition of the entire issued share capital of Flexible Engineered Solutions (Group) Holdings Limited (“FES”), a company based in the United Kingdom, for a total cash consideration of £50m, on a cash free / debt free basis, and which is subject to customary post-completion adjustments.

The acquisition is in line with Hunting’s broader growth strategy, outlined at the Group’s Capital Markets Day in September 2023, which detailed its expansion into the subsea equipment sub-sector of the energy industry. 

Renquip Completes Successful Management Buy-Out

RenQuip, a pioneering manufacturer of hydraulic and mechanical equipment, has successfully completed a management buy-out (MBO), marking a significant milestone in the company’s growth journey. The transaction was finalised on 19th June 2025, positioning the business for continued expansion in both domestic and international energy markets.

The MBO sees Managing Director Marc Gerrard and Technical Director John Morgan assume full control of the company’s strategic leadership. Both have been instrumental in RenQuip’s development since its launch in 2022 and bring more than 50 years combined technical and managerial experience in the energy engineering sector. 

Katoni Engineering are proud to announce the award of a key Repair Order (RO) contract with a major operator in the North Sea.

This marks an exciting milestone for our UK operations, as it expands our RO service line and introduces a new client relationship – a valued addition to our growing network within the oil and gas sector.

Jason Esplin, Head of Department (Piping), stated: “I’m absolutely delighted to bring this over the line. The trust that has been placed in us is something we don’t take lightly, and I’m proud of the team’s efforts in making this happen. This award strengthens our growing Repair Order capability and reflects the consistent quality and responsiveness we aim to deliver.” 

Revolutionising offshore welfare with lightweight, single point-lift deployment, enabling rapid portability between vessels and platforms.

Cargostore Worldwide, a leading global supplier of DNV and ISO certified shipping containers for onshore and offshore projects, has signed an exclusive global distribution agreement with Griffin Special Projects Ltd. to introduce the LiftaLoo, the next evolution in portable welfare units to the offshore market.

The partnership addresses a long-standing challenge in offshore operations; the lack of safe, hygienic and inclusive toilet facilities on structures like wind turbines and floating platforms. Despite industry efforts, this issue has continued to compromise crew well-being and site efficiency with personnel either having to wait for CTVs to return to the worksites before boarding and using the onboard facilities or making use of lower standard chemical flush solutions. 

3t Introduces Landmark Training to Empower Women in Saudi Arabia’s Energy Sector

3t, a global leader in training and blended learning for high-hazard industries, has unveiled a pioneering initiative to empower women in Saudi Arabia’s energy sector. Delivered at its state-of-the-art GTSC training centre in Dammam, the enhanced facilities and new programmes mark a significant milestone in supporting female workforce participation and advancing the Kingdom’s Vision 2030.

Officially approved by the Technical and Vocational Training Corporation (TVTC), the initiative provides women with access to world-class, industryaccredited training across the energy value chain.

As one of the first global training providers to offer specialist energy sector programmes for women in Saudi Arabia, 3t is proud to support the Kingdom’s drive to upskill its local workforce and foster inclusive growth across the region. 

Kystdesign signs historic agreement with DeepOcean on new E-ROV technology

Kystdesign has signed a historic agreement with DeepOcean for the delivery of new E-ROV technology. The agreement is driven by growing market demand for fully electric ROV on future IMR contracts. DeepOcean has signed an agreement with Kystdesign for the delivery of 2x ZEEROV IMR versions and 1x ZOROV observation ROV, with an option for an additional 6x ZEEROV IMR and 3x ZOROV.

Additionally, the agreement includes options for the further development of 4x specialized electric ROVs for heavier construction work and operations in areas with strong ocean currents. The first ROVs are scheduled for delivery in January 2027. The contract marks a significant breakthrough in modern E-ROV technology and will contribute to more sustainable offshore operations in the future. 

A New Dawn for Katoni Engineering

Cargostore Worldwide launches revolutionary welfare unit into the global offshore market

HUNTING is an energy services provider to the world’s leading national and international oil and gas companies, manufacturing and distributing products that enable the extraction of oil and gas.

www.huntingplc.com

Cargostore Worldwide is leading supplier of DNV 2.7-1 and ISO certified shipping and storage containers for offshore and onshore projects. We provide a complete range of offshore containers to support the oil & gas, offshore catering, and offshore renewable energy industries. All equipment is designed, built and certified to the DNV 2.7‐1 standard and available via our global depot network throughout the US West Coast, North Sea, East Asia, Middle East and East and West Africa.

www.cargostore.com

Kaseum are specialists in the design, development and manufacture of downhole tools. We are a highly experienced team with over 100 years’ experience in the development of new products for the perforation, logging, intervention, completion and drilling sectors. Our core skills include electronic, mechanical and software engineering with a particular emphasis on the design and manufacture of market-leading electro-mechanical intervention tools.

www.kaseum.com

Apex Industrial Chemicals Limited, headquartered in Aberdeen, Scotland, has been a leader in providing high-quality chemical solutions since 1982. Our expertise spans across various sectors, including industrial, oil and gas, energy, renewables, marine, transport, and catering. We are dedicated to designing, manufacturing, and supplying effective chemical products that meet stringent industry standards.

www.apexchemicals.com

At STR, our mission is to offer all customers a competitive edge by supporting integrated, forward-thinking technology and innovative engineering solutions, complete with flexible and dedicated support from project planning to project completion.

The Paradigm Group was established in the Netherlands in 2009 to develop a number of ‘new generation’ well intervention technologies. The main focus was around the use of Thermoplastic Composites both as coatings and as the main constituent of well intervention ‘wirelines’. In addition there was an exceptional level of in-house expertise in direct drive electric power systems for winches which were also targeted as a key area of focus.

www.paradigm.eu

SPACE are experts in the workplace, and for more than 27 years, have been helping organisations transform their working environments. Our business is built on our expertise, our experience and our consultative, collaborative approach to working with clients from start-up businesses to global corporates.

www.str-subsea.com www.spacesolutions.co.uk

UK North Sea Energy Review

By Tsvetana Paraskova

Actions needed to make the North Sea an economic and climate success, the prospects of offshore energy industry jobs, field developments, and asset sales marked the past few weeks in the UK North Sea oil and gas sector.

“While OEUK sets out in detail how homegrown energy adds more value to the UK economy than imports, the trade body acknowledges government and industry must do more to understand how the UK can manage electricity and fuel prices and bring down costs,” the industry group said.

OEUK’s plan says that by choosing to put home-produced energy at the heart of government strategies, the sector could deliver £200 billion investment this decade alone in UK offshore energies, and support UK supply chain firms, operators, and developers to win new work in floating and fixed offshore wind, carbon capture and storage, and hydrogen, apart from oil and gas.

A strategy focused on domestic energy could also help the sector provide an additional £150 billion of value to the UK economy and support 200,000 jobs through backing the responsible production of an additional 3 billion barrels of domestic oil and gas while meeting UK climate goals.

Offshore Energies UK is calling for industry and government to develop a new national energy strategy that places home produced energy at its core.

The UK is currently consulting on a new industrial strategy, the first for Britain in years. The success of such a strategy would depend on the crucial energy factor, according to the offshore industry body.

At present, the UK imports nearly 40 percent of the energy it consumes while domestic energy prices are the highest among G7 nations.

OEUK has also said the Government should remove the windfall tax on oil and gas profits by 2026. The leading trade body is calling for the windfall tax to be replaced with a competitive long-term mechanism that responds to future price shocks to encourage necessary investment in the UK’s energy future.

“In a country where today 75% of our energy comes from oil and gas, the solution is the responsible production of our own oil and gas from the North Sea, alongside the build out of renewable energy. It should not be a debate about one form of energy versus another – we need it all,” Whitehouse commented.

In a country where today 75% of our energy comes from oil and gas, the solution is the responsible production of our own oil and gas from the North Sea, alongside the build out of renewable energy.

“Decarbonisation must not mean deindustrialisation. Output in our energy intensive industries is at a 35-year low, yet our North Sea has the capability to provide all the energy it needs now and in future,” OEUK Chief Executive David Whitehouse said.

“Government and industry must work together to bring down energy costs while protecting the dividend that only home-produced energy can bring in terms of taxes paid, jobs supported, and value added to the economy.”

According to Whitehouse, “With the right investment climate and clear backing, UK offshore energy companies are prepared to invest up to £200 billion this decade across offshore wind, hydrogen and carbon storage alongside oil and gas. This investment would underpin the UK’s vision for a modern industrial Britain.”

“The sector needs action now to secure jobs, boost energy security, and build for the future. That means a commitment from government to deliver a mechanism in 2026 that creates a predictable response to future price shocks.”

A new report from Robert Gordon University warned in early June that the UK risks losing tens of thousands of offshore energy jobs by 2030 unless urgent and coordinated action is taken immediately.

The report, ‘Striking the Balance - Building a sustainable UK offshore energy workforce’, suggests a 2030 UK offshore energy workforce requirement for the oil, gas and renewables sectors of between 125,000 and 163,000 jobs, compared to today’s figure of approximately 154,000.

However, the specific UK oil and gas workforce is forecast to fall from 115,000 in 2024 to between 57,000 and 71,000 by the early 2030s.

In the lower case, the North Sea oil and gas workforce could shrink by approximately 400 jobs – the same number lost as a result of the closure of the Grangemouth refinery – every two weeks for the next 5 years, the report found.

Under a high-case scenario, workforce demand levels across the UK could hit over 210,000, but this will require the delivery of an additional 35 GW (or nearly 6 GW per year) of offshore wind and sustaining UK oil and gas activities for an extended period, similar to policies applied in Norway, Denmark, and the Netherlands.

If Scotland fails to capture the full range of offshore energy opportunities and the oil and gas decline continues to accelerate, the Scottishbased offshore energy workforce could decrease from approximately 75,000 in 2024 to between 45,000 and 63,000 by the early 2030s, according to the report.

“Inaction or simply slow progress will mean that UK offshore energy job numbers overall could drop by almost 20% to 125,000 by 2030, making the path towards net zero even harder to negotiate,” said Professor Paul de Leeuw, Director of the Energy Transition Institute at Robert Gordon University in Aberdeen.

In company news, Ithaca Energy has signed an agreement to buy a further 46.25-percent stake in the Cygnus gas field from Spirit Energy for a purchase price of £116 million. The Transaction, which is subject to NSTA consent, will raise Ithaca Energy’s operated interest in Cygnus to 85 percent.

NEO Energy has signed a deal to acquire Gran Tierra North Sea Limited (GTNSL), a 100-percent owned subsidiary of Gran Tierra Energy Inc. GTNSL holds a 100-percent equity interest in UKCS licence P2358 which includes the Serenity discovery, a potential future tie-back to the Bleo Holm FPSO. This creates potential growth and development opportunities as part of the recently announced strategic merger of NEO Energy with Repsol Resources UK Limited. Completion of the merger remains subject to approvals from the relevant authorities and regulatory consents.

Halliburton has won a five-year contract with Repsol Resources UK to optimize and support the full well lifecycle on their platform assets in the UK North Sea. Halliburton will provide subsurface

UK ENERGY REVIEW

technology, drilling and completion services, and digital solutions for major new developments. The company will deliver a rigless intervention framework that enables Repsol Resources UK to optimize well construction, production, and intervention to maximize plug and abandonment (P&A) operations.

Tattva Group has announced a £2 million investment in Project Development International (PDi), in a strategic push to expand its footprint in the North Sea, with a particular focus on engineering and procurement services to support operations and decommissioning. The investment aims to strengthen PDi’s core capabilities in subsea engineering and decommissioning, while enhancing its wider engineering services offering in topsides, Tattva said.

Fennex has secured a multi-year contract with energy company EnQuest for the deployment of its flagship AI-powered Behaviour-Based Safety System, BBSS. This partnership marks a major step in advancing data-driven safety practices across the UK operations of EnQuest, a leading UK-based operator focused on safely maximising production and extending the life of mature oil and gas assets.

Bilfinger UK has secured a contract with National Gas to maintain gas flow along National Transmission System pipelines by bolstering Operational Technology. The contract is expected to create up to 100 jobs, with Bilfinger UK undertaking the role of Principal Designer and Principal Contractor at key locations.

Odfjell Technology and Oilfield Service Professionals (OSP) have created a global strategic partnership to advance operational performance, efficiency, and innovation across international oilfield markets. The partnership aims to leverage combined engineering, technology, and project management capabilities to streamline execution and reduce downtime. A key objective is expanding joint services into key markets including the North Sea, Middle East, AsiaPacific, Brazil, and the Americas.

Flylogix said it had been contracted by Shell, Equinor, and Ithaca Energy to deliver essential methane emission measurement across the North Sea using Flylogix’s fleet of uncrewed aircraft. Under the new deals, Flylogix will have its drones fly for 16 UK oil and gas platforms and onshore terminals. 

THREE6O ENERGY A life cycle solutions company enabling a sustainable future.

Europe Energy Review

By Tsvetana Paraskova

Major deals for gas sales and gas field developments, as well as carbon capture and storage (CCS), battery storage, and renewable energy projects featured in Europe’s energy sector in the past weeks.

Oil & Gas

The Norwegian Ocean Industry Authority, Havtil, has given Equinor consent to install a new connection point on the Snøhvit gas pipeline for future connection of gas exports from the Goliat field via the Snøhvit pipeline, and on to Hammerfest LNG. The connection to the Snøhvit gas pipeline will be carried out using a Hot Tap concept, which involves connecting to an operating gas pipeline.

Equinor and Centrica have signed a longterm gas sales agreement that would help strengthen the UK energy security. Under the deal, Equinor will deliver 55 TWh of natural gas per year (around 5 billion cubic meters) for a period of 10 years starting 1 October 2025 at terms reflecting market prices. The total contract value would be around £20 billion assuming current prices, Equinor said.

“The UK and the North Sea is a core area in our long-term ambitions to remain a supplier of reliable energy and to help decarbonise societies and industries,” commented Equinor’s UK Country Manager Alex Grant.

In Azerbaijan, which aims to boost gas sales to Europe now that Russia’s gas is scarce, bp has approved the next major phase of development of giant Shah Deniz gas field. In addition, the UK supergiant signed a series of contracts paving the way for growth and additional production while deepening its partnership with the country and state oil company, SOCAR.

The agreements include the final investment decisions for the next major phase of development of the giant Shah Deniz gas field – Shah Deniz Compression – as well as for two projects – for terminal electrification and solar power to enable emissions reductions. bp also signed agreements to access two new exploration and development licences and introduce a new partner to accelerate exploration on a third.

In a report in early June, the Industry and Regulators Committee also suggested that regional zonal pricing should enable better use of existing grid capacity and lower the cost of electricity, provided that the transition and its risks are managed well.

The report welcomed Ofgem’s decision to prioritise projects that are strategically necessary to meet the clean power target and warns that without greater skills, resources, and a more strategic approach, the planning system will remain a key barrier to delivering the infrastructure needed.

Given the scale of changes needed to the planning, regulation and delivery of energy infrastructure, and the UK’s historic record of delivering major infrastructure projects, our report questions the feasibility of meeting the clean power target.

Chair of the Committee, Baroness Taylor of Bolton.

“Given the scale of changes needed to the planning, regulation and delivery of energy infrastructure, and the UK’s historic record of delivering major infrastructure projects, our report questions the feasibility of meeting the clean power target,” said Chair of the Committee, Baroness Taylor of Bolton.

Shah Deniz Compression is one of bp’s 8-10 major projects expected to start up between 2028 and 2030. It is expected to contribute to growing bp’s global upstream production to 2.3-2.5 million barrels of oil equivalent per day (boed) by 2030, with capacity to increase further to 2035.

Low-Carbon Energy

The UK is at risk of missing its clean power target to have at least 95 percent low-carbon electricity by 2030 unless the government drastically steps up the scale and pace of building more energy generation and network infrastructure, the House of Lords Industry and Regulators Committee has warned.

Offshore Energies UK (OEUK), the main offshore industry body, said the opening of UK-EU talks on key areas such as grid linkage and emissions trading offers opportunities to drive down costs for homes and businesses, boost energy security, and accelerate the drive to net zero.

“I hope we can work with our European partners to drive down costs and unlock a new era of innovation and collaboration across our shared energy mix from offshore wind, hydrogen to carbon capture – all secured by domestic oil and gas production and our world class supply chains,” OEUK’s head of energy policy Enrique Cornejo commented.

The North Sea Transition Authority (NSTA) has issued a call for nominations for potential carbon storage locations. The process of seeking pre-application nominations should encourage companies to focus on areas where they have already done some technical work, encouraging higher quality applications and likely cutting time to project delivery, the NSTA said.

Companies submitting nominations by 31 July will be required to submit spatial data and describe a high-level project description, which will allow the NSTA, Crown Estate Scotland (CES) and The Crown Estate (TCE) to consider any spatial planning interactions and opportunities.

After 31 July, the NSTA will evaluate the proposals, working closely with CES, TCE and the Department of Energy Security and Net Zero to align carbon storage licensing and seabed leasing, and ensure minimal impact on other offshore sectors and users such as current or planned windfarms and tidal schemes.

A project backed by the Welsh Government is aiming to develop the next generation of tidal stream turbine blades, with the potential to transform the tidal energy industry. The Advanced Manufacturing Research Centre (AMRC) Cymru, based in Broughton, is teaming up for the project with Menter Mon and the Offshore Renewable Energy (ORE) Catapult’s Welsh team to improve the efficiency, durability, and overall performance of tidal energy blades.

In company news, Noble Corporation announced a new contract with bp for the Noble Innovator to drill six firm wells for the Northern Endurance Partnership Project (NEP) in the North Sea—a carbon capture and storage (CCS) project, to which bp provides operatorship services. The contract is expected to commence in Q3 2026 and contains an option for two additional wells.

TotalEnergies has bought a pipeline of 8 solar projects with a capacity of 350 MW and 2 battery storage projects with a capacity of 85 MW in the UK from renewable energy company Low Carbon. The solar projects are at an advanced stage of development and are targeted to be operational by 2028.

Kishorn Port on the west Highland coast has secured an investment of up to £24 million by Highlands and Islands Enterprise (HIE) in the £42.2-million Phase 1a expansion project to enable Kishorn to play a pivotal role in the delivery of offshore wind projects in Scotland and elsewhere. The project includes expansion of the dry dock and land reclamation, enabling the manufacture of floating offshore wind foundations.

Peel Ports Clydeport has invested £3 million in infrastructure to support growing demand for handling huge wind turbine components for the renewable energy sector at a key facility.

Statkraft, Europe’s largest generator of renewable energy, has proposed the development of a green hydrogen facility at Hunterston, the former coal terminal in Ayrshire. Clydeport has exchanged an option agreement with Statkraft to explore the potential development at its Hunterston PARC (Port and Resource Campus) site. The proposed facility would be used for the production, storage, and export of hydrogen from the UK on vessels in the form of ammonia.

Polish refiner Orlen has opened Poland’s first offshore wind farm installation terminal, which will serve as a key base for Orlen’s phase two offshore wind projects and will also be available to external operators.

TotalEnergies has launched its largest solar power plant cluster in Europe, near Seville

in Spain. The cluster consists of five solar projects with a total installed capacity of 263 MW. This solar field will produce 515 GWh per year of renewable electricity, equivalent to the consumption of over 150,000 Spanish households, and will avoid 245,000 tons of CO2 emissions per year. Most of the electricity produced will be sold through longterm power purchase agreements (PPAs) and the rest will be sold on the wholesale market.

“We warmly thank the Spanish authorities at both the regional and national levels for supporting this solar project that is contributing to Spain’s ambition of 80% of renewables in its mix by 2030”, stated Olivier Jouny, Senior Vice President Renewables at TotalEnergies.

TotalEnergies has also welcomed HitecVision, a Norwegian investment company specializing in energy, as a partner with 50 percent in Polska Grupa Biogazowa (PGB), Poland’s leading biogas company with 20 units in operation and a production capacity of over 450 GWh of equivalent biomethane.

“This transaction will enable PGB to continue its growth in a country where biogas is rapidly developing and is in line with the farmdown business model applied to our renewable assets in order to maximize the profitability of our investments”, said Stéphane Michel, President of Gas, Renewables & Power at TotalEnergies. 

USA Energy Review

By Tsvetana Paraskova

US crude oil production is set to decline from record highs while natural gas prices in America are expected to rise from 2024 lows amid constantly growing LNG exports.

In May, the number of active rigs decreased by much more than the EIA had expected in the May STEO, based on data from Baker Hughes. With fewer active drilling rigs, the administration now forecasts US operators will drill and complete fewer wells through 2026. On an annual basis, the EIA now forecasts crude oil production will average a bit more than 13.4 million bpd in 2025 and a bit less than 13.4 million bpd in 2026.

For the second half of the year, the EIA expects slowing global oil production growth—led by relatively flat US crude oil production.

Despite the recent OPEC+ announcement of its third consecutive planned monthly crude oil production increase for July 2025, the EIA still anticipates OPEC+ producers will pump below the current target path, aiming to limit increases in global oil inventories and support falling prices. Per EIA’s estimates, OPEC+ will increase its crude oil production by 300,000 bpd this year, compared with a decrease of 1.4 million bpd in 2024, before increasing by 500,000 bpd in 2026.

Strong export growth that persistently outpaces US natural gas production would result in higher natural gas prices this year and next, according to the EIA.

The energy administration expects natural gas prices to increase throughout the summer as production declines slightly and demand for air conditioning increases the use of natural gas in the electric power sector.

The Henry Hub spot price in the EIA forecast averages more than $4.30/MMBtu in the second half of 2025, up from the May average of $3.12/MMBtu.

Domestic consumption and exports combined will increase by nearly 4 Bcf/d this year, while domestic dry natural gas production would grow by less than 3 Bcf/d.

While national indicators point to a cooling labor market, the energy services sector continues to demonstrate underlying strength

The oil and gas associations in Texas and the US noted a still resilient jobs market in the oilfield services sector despite a general cooling of the labour market. Finally, the oil lobby keeps welcoming legislation by the Trump Administration aimed at boosting US resource development and production.

US Crude Oil Production Set to Decline Next Year

US crude oil production is expected to decline from an all-time high of 13.5 million barrels per day (bpd) in the second quarter of 2025 to about 13.3 million bpd by the fourth quarter of 2026 because of decreasing active drilling rigs and declining oil prices, the US Energy Information Administration (EIA) said in its Short-Term Energy Outlook (STEO) in June.

“We expect countries outside of OPEC+ will drive global liquid fuels production growth this year, increasing production by 1.1 million b/d. However, OPEC+ drives growth next year in our forecast, as NonOPEC+ growth in our forecast slows to 0.2 million b/d, with growth from Brazil, Guyana, and Canada being partly offset by a slight drop in U.S. production,” the EIA noted in its monthly outlook on the US and global energy markets.

Although natural gas inventories have recently moved above the five-year average, the EIA expects that as demand persistently outpaces supply through much of this year, inventories will fall back below the five-year average by October, putting upward pressure on prices.

Energy Workforce President Molly Determan

The energy services sector remained resilient in May amid signs of a broader national labour market slowdown, the latest jobs report by the Energy Workforce & Technology Council showed in June.

Strong LNG Export Growth to Support US Natural Gas Prices

In the same outlook, the EIA forecasts the benchmark US Henry Hub spot price to average about $4.00 per million British thermal units (MMBtu) in 2025 and $4.90/MMBtu in 2026, considerably higher compared with $2.20/MMBtu in 2024.

However, the number of jobs declined. Total jobs in the energy services sector reached 638,876 in May, a decrease of 1,391 positions from April, according to preliminary data from the Bureau of Labor Statistics (BLS) and Energy Workforce analysis.

“While national indicators point to a cooling labor market, the energy services sector continues to demonstrate underlying strength,” said Energy Workforce President Molly Determan.

“Even with monthly declines, our industry remains focused on stability, efficiency, and long-term growth, powered by a workforce essential to American energy leadership.”

API Welcomes US EnergySupportive Legislation

American Petroleum Institute (API) President and CEO Mike Sommers commented on the US House of Representatives passing the 2025 tax reconciliation bill, saying,

“We applaud the House of Representatives for passing the One Big Beautiful Bill Act to help restore American energy dominance.”

“By preserving competitive tax policies, beginning to reverse the ‘methane fee,’ opening lease sales and advancing important progress on permitting, this historic legislation is a win for our nation’s energy future,” Sommers said.

“We look forward to working with the Senate to strengthen pro-investment provisions and keep America at the forefront of energy innovation.”

The US Department of the Interior proposed in early June rescinding a rule put in place last year that added new restrictions on oil and gas development in the National Petroleum Reserve in Alaska.

“Rescinding the 2024 rule will remove regulations that are inconsistent with the Naval Petroleum Reserves Production Act of 1976, restore the original intent of the Act for the management of the area, and eliminate roadblocks to responsible energy production,” DOI said.

The Reserve, which encompasses approximately 23 million acres on Alaska’s North Slope, was set aside by Congress for oil and gas exploration and development as a matter of national energy security and policy in reaction to the oil crisis in the 1970s.

API applauded the proposal to rescind restrictions. Dustin Meyer, Senior Vice President of Policy, Economics and Regulatory Affairs, said “Our industry is committed to the safe, responsible development of Alaska’s vast energy resources, and we look forward to working with Secretary Burgum to advance American energy dominance.”

The Trump Administration said in June that fuel economy standards issued under former President Biden exceeded legal authority.

Economy Program.” The rule explains that the Biden Administration ignored statutory requirements in CAFE barring consideration of electric vehicles when setting fuel economy standards.

“The previous administration illegally used CAFE standards as an electric vehicle mandate – raising new car prices and reducing safety,” US Transportation Secretary Sean P. Duffy said in a statement.

Under the so-called Corporate Average Fuel Economy Program (CAFE), the Biden Administration included electric vehicles in calculating fuel economy regulations.

“Our industry is committed to the safe, responsible development of Alaska’s vast energy resources, and we look forward to working with Secretary Burgum to advance American energy dominance.”

Now the U.S. Department of Transportation’s National Highway Traffic Safety Administration (NHTSA) published a final rule, “Resetting the Corporate Average Fuel

“Resetting CAFE standards as Congress intended will lower vehicle costs and ensure the American people can purchase the cars they want.”

API welcomed this rule, too, with president and CEO Sommers saying “The previous administration’s rules effectively banned new gaspowered cars and trucks— overstepping their authority and facing clear pushback from voters.”

Sommers continued, “Every American should have the freedom to choose the vehicle that works best for them, and we will continue working with the administration on this critical pillar of an energy dominance agenda.” 

Dustin Meyer, API Senior Vice President of Policy, Economics and Regulatory Affairs

Middle East Energy Review

By Tsvetana Paraskova

The OPEC+ group continues to unwind their oil production cuts, bringing more supply to the market during the peak summer demand season, while the biggest national oil companies in the Middle East signed a series of deals with US firms.

The healthy market fundamentals and expectations that summer oil demand growth will hold strong prompted these OPEC and non-OPEC producers to pledge additional hikes to supply.

However, they noted, as usual, that “The gradual increases may be paused or reversed subject to evolving market conditions. This flexibility will allow the group to continue to support oil market stability.”

Market analysts see the continued output hikes as OPEC+ showing reduced tolerance to overproducing members and a power play to regain market share lost to US producers, who have been boosting production at oil prices above $70 per barrel, while OPEC and its allies in the OPEC+ have had to withhold supply.

OPEC+ Boosts Oil Production

The OPEC+ producers that have been cutting production since 2022 proceeded with easing the cuts and decided in early June to add another 411,000 barrels per day (bpd) to their combined output in July.

Saudi Arabia, Russia, Iraq, UAE, Kuwait, Kazakhstan, Algeria, and Oman are raising production by 411,000 bpd for the third consecutive time, citing “current healthy oil market fundamentals and steady global economic outlook.”

Warren Patterson and Ewa Manthey, commodities strategists at ING, expect the OPEC+ producer group to continue with the large increases in the coming months.

“This would mean that the full 2.2m b/d of supply will be brought back by the end of the third quarter of this year, 12 months ahead of schedule,” they said after OPEC+ announced the hike for July.

“This is the key assumption behind our price forecast for ICE Brent to average US$59/bbl in the fourth quarter.”

OPEC+ producers also decided at the end of May to mandate the OPEC Secretariat to develop a mechanism to assess the maximum sustainable production capacity (MSC) of the participating countries which will be used as reference for 2027 production baselines for all OPEC+ producers.

Some big OPEC producers in the Middle East, including Iraq, the United Arab Emirates (UAE), and Kuwait, plan to raise their oil production capacity in the coming years. These countries have argued that they deserve higher baseline production levels as they expand capacity. The UAE, for example, last year argued for – and won – higher baselines for 2025 and 2026.

As the baselines are used when OPEC and OPEC+ set production cuts, the beginning of estimates for 2027 baselines suggests that the producer group will continue to manage its own supply and could cut or raise production, depending on market conditions.

Aramco and ADNOC Sign Energy Partnerships with US Firms

Aramco, the Saudi state oil firm and the world’s biggest oil company by any measure, signed a total of 34 Memoranda of Understanding (MoUs) and agreements, with a potential total value of about $90 billion, with major US companies.

The MoUs and agreements with US companies – including Sempra Infrastructure, NextDecade, ExxonMobil, Amazon/ AWS, NVIDIA, and Qualcomm – cover collaborations and partnerships relating to a range of Aramco’s activities, such as LNG, fuels, chemicals, emission-reduction technologies, AI and other digital solutions, manufacturing, asset management, shortterm cash investments, and procurement of materials, equipment, and services.

In technical services, Aramco signed MoUs to reflect the existing relationships with strategic US suppliers—SLB, Baker Hughes, McDermott, Halliburton, Nabors, Helmerich & Payne, Valaris, NESR, Weatherford, Air Products, KBR, Flowserve, NOV, Emerson, GE Vernova, and Honeywell.

“As Aramco pursues an ambitious valuedriven growth strategy, we believe that aligning with world-class partners supports further development of our operations, strategic diversification of our portfolio, industrial innovation, and ongoing capability development within the Kingdom,” Aramco President and CEO Amin Nasser said.

Separately, Aramco announced it had achieved a world-first by successfully commissioning a megawatt (MW)-scale renewable energy storage system to power gas production activities. It is the first deployment globally of an Iron-Vanadium (Fe/V) flow battery as a backup solar power source for gas well operations.

The battery is specifically engineered to withstand the hot climate of Saudi Arabia and achieve optimal performance under extreme weather conditions.

“Aramco already powers a large number of remote gas wells with solar panels connected to lead-acid battery systems, but our groundbreaking flow battery technology offers a flexible solution for diverse renewable energy storage requirements, making it an attractive option for a variety of industrial applications,” said Ali A. Al-Meshari, Aramco Senior Vice President of Technology Oversight & Coordination.

MIDDLE EAST ENERGY REVIEW

In the United Arab Emirates (UAE), Abu Dhabi national oil company ADNOC announced multiple agreements with US energy majors during the UAE-US business dialogue with US President Donald Trump. The agreements will potentially enable $60 billion of US investments in UAE energy projects across the lifespan of the projects.

The agreements include a field development plan with ExxonMobil and INPEX/JODCO to expand the capacity of Abu Dhabi’s Upper Zakum offshore field through a phased development.

ADNOC also signed a strategic collaboration agreement with Occidental to explore increasing the production capacity of Shah Gas field’s capacity to 1.85 billion standard cubic feet per day (bscfd) of natural gas, from 1.45 bscfd, and accelerating the deployment of advanced technologies in the field.

Zones Abu Dhabi (KEZAD), Dubai Industrial Park, Jebel Ali Free Zone (JAFZA), Sharjah Airport International Free Zone (SAIF Zone), and Umm Al Quwain. These will create more than 3,500 highly skilled private sector jobs and manufacture a wide range of industrial products including pressure vessels, pipe coatings, and fasteners.

State firm QatarEnergy, which is working on the world’s biggest LNG project expansion project in Qatar, believes that natural gas will be the backbone of growth of all economies and gas “is here to stay for the next century,” Saad Sherida Al-Kaabi, Qatar’s Minister of State for Energy Affairs and President and CEO of QatarEnergy, said World Gas Conference (WGC) in Beijing in May.

We will more than double LNG production from the current 77 million tons to 160 million including production from our Golden Pass project in Texas, which will come online later this year

“The agreements reinforce the shared commitment of the UAE and US to maintaining global energy security and the stability of energy markets. The enterprise value of UAE energy investments into the US is set to reach $440 billion by 2035, as part of the UAE’s $1.4 trillion investment plan into the country,” ADNOC said in a statement.

Sultan Al Jaber, UAE Minister of Industry and Advanced Technology, ADNOC Managing Director and Group CEO, commented,

“We see significant opportunities for further UAEUS partnerships across the energy-AI nexus and we look forward to working with our American partners to unlock long-term sustainable value and drive socioeconomic progress.”

ADNOC has also said that its partners across its supply chain have committed to invest AED3 billion ($817 million) in manufacturing facilities across the UAE.

The facilities are located across Industrial City of Abu Dhabi (ICAD), Khalifa Economic

Referring to Qatar’s North Field expansion to add substantial LNG export capacity, Al-Kaabi said that QatarEnergy will start up the first LNG train from the North Field East development –which has a 32 million ton per annum LNG production capacity – by the middle of 2026.

The North Field West project is in the engineering phase and will be going into the construction phase in 2027.

“We will more than double LNG production from the current 77 million tons to 160 million including production from our Golden Pass project in Texas, which will come online later this year,” Al-Kaabi noted.

“QatarEnergy will be the largest single LNG exporter as a company. While Qatar, as a country, will be the second largest exporter of LNG after the United States for a very long time,” Al-Kaabi said.

“We will play a very big role in helping economies around the world to flourish and to grow, with the cleanest fossil fuel available.” 

Norway Energy Review

By Tsvetana Paraskova

Norway Bets on Floating Wind As Oil and Gas Revenues Stay High

Revenues from the petroleum sector have been at historically high levels, and the government expects these revenues to remain high in 2025, the Norwegian government said, commenting on the revised national budget for this year.

According to official government estimates, Norway’s net cash flow from the oil and gas sector will be 698 billion Norwegian crowns, or about $70 billion, this year.

“The significant revenues from the petroleum sector contribute to financing the welfare state,” Norway’s Minister of Energy Terje Aasland said.

The revenues are expected to provide about 21 billion crowns, or about $2 billion, in increased budget flexibility for every future budget, the minister added.

Activity and Investment Remain High

The total petroleum production from the Norwegian continental shelf reached approximately 241 million standard cubic meters of oil equivalents in 2024. This was the highest level of oil and gas production in Norway since 2009. Natural gas production hit its highest level ever last year, the government said.

Investments in the petroleum industry continue to be at a high level, also thanks to ongoing development projects. Investments in the petroleum industry are estimated to reach 264 billion crowns, or $26.2 billion, in 2025, the Norwegian government says.

As projects are completed, investments are set to decrease in the following years. The reduction is expected to be especially significant for new platforms and production ships, which are particularly important for parts of the shipyard industry.

“The government is facilitating continued exploration, improved recovery, and the development of discoveries through stable and predictable framework conditions,” Aasland said.

“For us to succeed, it is important that companies utilize all the business opportunities in our oil and gas resources in the future.”

The Norwegian Offshore Directorate held in early June its annual event Technology Day to hear insights about new technology on the NCS.

The Norwegian Offshore Directorate aims to stimulate the industry to develop, cooperate more closely, and adopt new technology to an even greater extent, the regulatory body said.

Norway continues to generate high revenues from its oil and gas industry and keeps supporting continued exploration and production on its continental shelf. At the same time, Western Europe’s top oil and gas producer is backing floating offshore wind development and has just announced a tender for three project areas in its waters.

Norway’s Petroleum Revenues

Higher oil and gas output offshore Norway continues to generate large revenues for the country from its petroleum industry, the government said in May.

This year, oil and gas production is expected to be around 3 percent lower compared to 2024. Due to high development activity on the shelf, oil and gas output is set to remain stable in the years following 2025.

Norwegian petroleum production is an important contributor to Europe’s energy security, minister Aasland said in a statement.

“In 2024, we had record-high gas production, which is particularly important for ensuring Europe’s energy supply. We will continue to develop the sector so that we can deliver stable energy to our neighbors while ensuring jobs, value creation, and state revenues from the industry,” Aasland noted.

The goal is new technology to permeate all parts of the value chain. This will result in good resource management and the greatest possible value creation, the directorate said.

In new discoveries news, OKEA and the licensees in production licence 055 have discovered oil along the eastern flank of the Brage field in the North Sea. The discovery was made in the southern part of the Prince prospect in wildcat well 31/4-A-23 G. Preliminary estimates place the size of the discovery at between 1.9 million barrels and 17.5 million barrels of oil equivalent.

The licensees will now assess the deposit as part of the further development of the operational Brage field.

Aker BP ASA and its partners have made an oil discovery in the so-called E prospect near the Skarv field. Preliminary calculations of the size of the discovery made in the Garn Formation are 3-7 million barrels of recoverable oil equivalent. The licensees will consider the discovery in the Garn Formation for a potential tie-back to the Skarv FPSO.

Floating Wind Tender

Norway announced in May a tender for three project areas for floating offshore wind in the first such competition in the country. The Ministry of Energy announced the competition for three project areas for floating offshore wind at Utsira Nord off Norway’s southwest coast.

The project aims to facilitate increased renewable power production, technological development, and new growth opportunities for the supplier industry. The application deadline is September 15.

Norway will subsidize the projects, for a total of $3.5 billion (35 billion Norwegian crowns) cap for state aid. The winner of the competition shall establish a project as close to 500 MW as possible, depending on the chosen turbine size.

“Utsira Nord is an important first step in the development of commercial floating offshore wind on the Norwegian continental shelf,” minister Aasland said.

“The model for allocating project areas and state aid is tailored to floating offshore wind and can contribute to both technological development and cost reductions for future projects.”

Two new demo offshore wind projects are ready to test in Norway, Norwegian Offshore Wind said.

of installing one full-scale floating offshore wind turbine in 2028.

“Getting more projects in the water is essential to driving progress and contributing to cost and risk reductions in this pivotal time for floating offshore wind,” said Cecilia GirardVika, Director of METCentre.

The Norwegian Offshore Directorate is launching a new interactive map of deep sea data, Deep Sea Surveys. The new map provides an overview of mapping and sampling carried out in the deep sea on the Norwegian continental shelf.

Utsira Nord is an important first step in the development of commercial floating offshore wind on the Norwegian continental shelf...

Minister of Energy Terje Aasland

California-based Aikido will deploy a first-ofits-kind 15 MW demo project, called ‘AO60’ at the Marine Energy Test Centre (METCentre). Once installed in 2027, the platform will be one of the largest floating wind platforms constructed and deployed to date.

Norwegian firm Odfjell Oceanwind (OOW) has secured a slot with 24 MW capacity grid connection at the same site, with the ambition

The directorate also announced in early June that a wildcat well drilled by Harbour Energy Norge and licensees in the “Havstjerne” storage project confirmed a reservoir that is suitable for injection and storage of carbon dioxide (CO2). Well 9/6-1 was drilled in the North Sea around 30 kilometres southeast of the Yme platform and around 120 kilometres southwest of Farsund. An injection test has been conducted, with positive preliminary results.

The data will now be subject to further analysis, and the results will become part of the basis for future decisions regarding investment in the Havstjerne storage project.

This was the fourth well drilled to investigate potential commercial storage of CO2 on the Norwegian continental shelf.

Skarv FPSO; Source: Aker BP

Australia Energy Review

By Tsvetana Paraskova

Australia Boosts Gas Development As Battery Investment Soars

Australia has approved an extension to the operating life of its oldest and biggest gas processing project and moved closer to starting up a new LNG plant, while developers boosted battery storage investments.

North West Shelf Gas Extension

Following six years of extensive federal and state reviews and delays due to challenges in court, Australia’s federal government approved in May a proposal that would see the operating life of its biggest and oldest LNG plant extended to 2070.

The Australian Government has been considering a proposal to continue the use and extend the operating life of the North West Shelf gas processing plant in Karratha, Western Australia, beyond the expiry of its current approval in 2030.

Murray Watt, Australia’s federal Minister for the Environment and Water, made a proposed decision to approve the North West Shelf extension, subject to strict conditions, particularly relating to the impact of air emissions levels from the operation of an expanded on-shore Karratha gas plant.

The project’s operator, Australia’s top gas producer Woodside, first proposed the extension of the operating life of the North West Shelf Project in 2018. State and federal governments have been reviewing the plans to extend life beyond 2030, as it was originally planned, amid hundreds of appeals by activists campaigning to preserve the environment and the cultural heritage of the local people.

Woodside received the Western Australia state government approval in December 2024 after six years of assessment and appeals.

Extending the environmental consent for the project, which began producing gas in 1984, means that Woodside and its partners in the project could continue to deliver gas using existing infrastructure.

“This proposed approval will secure the ongoing operation of the North West Shelf and the thousands of direct and indirect jobs that it supports,” said Liz Westcott, Woodside Executive Vice President and Chief Operating Officer, Australia.

As part of the State Government approval in December 2024, the North West Shelf committed to a range of environmental management measures, including a significant reduction in air emissions and measures to manage greenhouse gas emissions and to reduce them over time, Woodside noted.

The North West Shelf Project has supplied more than 6000 petajoules of domestic gas, powering homes and industry in Western Australia. If used for just household electricity, this is enough to power homes in a city the size of Perth for approximately 175 years, Woodside says.

In a separate development, Woodside announced in May that the Scarborough Energy Project had achieved a major engineering milestone with the joining together of the topsides and hull for the Floating Production Unit (FPU).

The joining of the two mega-structures is a significant step forward for the Scarborough Energy Project as it progresses towards first LNG cargo, targeted for the second half of 2026, the company said.

The Scarborough Energy Project is now over 82 percent complete.

Once complete, the FPU will be moored 375 kilometres off the coast of Karratha, Western Australia. The Scarborough Energy Project is set to produce up to 8 million tonnes of LNG per year and contribute up to 225 terajoules a day of domestic gas supply into the Western Australian market.

Producers Call for Sensible Energy Policies

Australian producers now have the opportunity to take real actions that deliver the Government’s Future Gas Strategy, Woodside CEO Meg O’Neill said in an address to the 2025 AEP Conference & Exhibition at the end of May.

However, forecasts of looming supply shortfalls on both the east and west coasts and weakened investor confidence in investing in new supply could put Australia’s energy leadership at risk, O’Neill said.

“Certainty around Australia’s energy and climate policies, environmental regulation and timely approvals is critical to driving investment,” the executive added.

“I am encouraged by evidence – including the Government’s Future Gas Strategy –that policymakers are increasingly willing to recognise and speak up for the critical importance of natural gas, including as the stabilising partner to higher levels of renewables and as a lower emissions source of power than coal,” O’Neill noted.

Woodside’s boss called for exploration to resume in earnest in Australia. This would begin with regular offshore acreage licensing rounds, and clear regulations around the well-proven and safe technology of seismic surveys.

“We must get exploration going now to ensure the energy future of the 2030s and 2040s is secure,” O’Neill said.

At the same AEP Conference, Kevin Gallagher, CEO at another major Australian producer, Santos, said that Australia needs to develop more of its own gas supply.

“Affordable energy is quite simply the lynchpin of national success. Without it, we pay more for everything,” Gallagher said.

The energy transition is slower than initially expected as energy demand continues to grow, the executive added, but noted that Australia is “exceptionally well-positioned” to lead in carbon capture and storage (CCS).

“We have world-class geological storage basins and we have the project experience,” Santos’ chief executive said.

In conclusion, Gallagher stated, “The world has an insatiable appetite for energy. And it will need all forms of energy to feed that appetite.”

At the end of May, the Victorian Government delivered a positive assessment for Viva Energy’s LNG terminal project in Geelong, marking a significant step in ensuring a secure energy future for the State.

Victorian Planning Minister Sonya Kilkenny found that, subject to conditions, the project can proceed with acceptable environmental effects.

The gas terminal unlocks a pathway to bring LNG from Australian gas fields or around the world, effectively acting as a virtual pipeline to deliver gas directly to where it is needed most – the major Victorian markets of Melbourne and Geelong, Viva Energy said.

Australia’s Energy Storage Investment Continues To Soar

Developers maintained the momentum in investment in energy storage projects in Australia in the first quarter of 2025, the Clean Energy Council’s Quarterly investment report showed at the end of May.

Six storage projects representing 1,510 MW of capacity and 5,016 MWh of energy output reached financial close in Q1 – the second highest quarterly result for new financially committed storage projects.

It is encouraging to see sustained momentum in investment for large-scale battery and storage projects as they are critical to achieving reliable and affordable energy generation through renewables such as wind and solar, said Arron Wood, Clean Energy Council Chief Policy and Impact Officer.

“Subdued levels of investment are fairly typical in the first quarter of the year; however, the clear-cut result of this election has given the Government a mandate to continue leading Australia’s transition to clean energy and that has provided markets with policy certainty and a clear signal about where to invest.” 

Image: Akaysha Energy / Powin Energy.

Isolated Pipeline

Zero Energy Zone

Taper Lock Grips

Double Block & Monitor Isolation

Dual Leak-Tight Seals

Pipeline Pressure

1 YEAR AGO

1 Year Ago (July 2024):

In July 2024, Brent crude oil averaged around $83 per barrel. Prices were influenced by OPEC+ production cuts, steady global demand, and geopolitical uncertainties. Market volatility remained moderate. Economic recovery in key regions supported stable oil consumption, while inflation concerns and interest rate trends continued to shape investor sentiment globally.

5 YEARS AGO

5 Years Ago (July 2020):

In July 2020, Brent crude traded around $43.24 per barrel, recovering from the dramatic crash earlier that year due to COVID-19 lockdowns. OPEC+ output cuts and gradually returning demand helped prices stabilize. However, uncertainty lingered due to virus resurgence, travel restrictions, and slow economic recovery, keeping oil markets cautiously optimistic yet fragile.

10 YEARS AGO

10 Years Ago (July 2015):

In July 2015, Brent crude hovered around $47.70 per barrel, sharply down from 2014 highs. Oversupply from U.S. shale production and a decision by OPEC to maintain output pressured prices. Slowing demand in China and a strong U.S. dollar further impacted oil markets, fueling a bearish sentiment and prolonged price weakness.

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

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

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Energy projects and business intelligence in the energy sector

The EIC delivers high-value market intelligence through its online energy project database, and via a global network of staff to provide qualified regional insight. Along with practical assistance and facilitation services, the EIC’s access to information keeps members one step ahead of the competition in a demanding global marketplace.

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The EIC is the leading Trade Association providing dedicated services to help members understand, identify and pursue business opportunities globally.

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

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

WEST FEIRAN OIL DISCOVERY

Petrobel has announced the discovery of oil through the drilling of the West Ferian-2 well. The oil was discovered within the Asal sands, and on test flowed at 2,660 barrels of oil per day (bbl/d). Additional studies are currently being undertaken to assess the reserves.

WASSANA REDEVELOPMENT PROJECT

Valeura has taken the FID for the project with first oil expected in Q2 2027 and peak production anticipated at 10,000 b/d. The redevelopment of the Wassana field will be based on a new-build Central Processing Platform (CPP) with 24 production well slots. The new CPP is planned to replace the existing MOPU infrastructure.

APHRODITE SUBSEA TIE-BACK

Subsea7 has been awarded a contract for the transportation and installation of subsea equipment. Project management and engineering activities will begin immediately at Subsea7’s office in Houston, Texas, with offshore operations planned for 2027. Shell announced the FID for the project in June and production is expected to peak at around 18,400 boe/d.

SEA LION OIL FIELD (PHASE 1)

Several letters of intent and memoranda of understanding have been signed, covering the supply of the FPSO and key subsea equipment. Additionally, talks are ongoing to secure a suitable drilling rig. A final investment decision is expected to be taken in the second half of 2025.

UMM SHAIF – LONG TERM PRODUCTION PHASE 2 (LDTP-2)

First steel cutting for the project has been undertaken at McDermotts yard in Jebel Ali. McDermott, as the EPC contractor, are responsible for the construction of a water injection platform, five wellhead topsides, well fluid & water injection pipelines and 30 km of subsea cables.

SHAH DENIZ COMPRESSION PROJECT

The Shah Deniz Compression (SDC) project has achieved FID. The $2.9 billion SDC project will include construction of a new, electrically powered, unmanned compression platform (eNUI) in 85 metres of water depth, located about 3 kilometres from the existing Shah Deniz Bravo (SDB) platform. The new facility will house four 11-MW compressors and will compress gas received from both Shah Deniz Alpha (SDA) and SDB platforms.

BUKIT PANJANGJENGGOLO FIELD DEVELOPMENT

Velesto has announced the award of a contract to provide drilling rig services for Petronas’ PSC in Indonesia. Under the contract, Velesto will deploy the NAGA 8 jack-up rig covering a firm period of four years which includes 12 firm wells and 3 optional wells.

EKOFISK PREVIOUS PRODUCED FIELDS (PPF) DEVELOPMENT PROJECT

Subsea7 has been awarded a FEED contract under a framework agreement with ConocoPhillips. The FEED study will ensure technical definition of the proposed subsea development. The company stated that work will commence immediately in its Norway office. In case of positive FID and government authority approval, ConocoPhillips can award a SURF contract to Subsea7.

ATAPU OIL FIELD (PHASE 2 – P84 FPSO)

ABB has been awarded a contract by Seatrium to design and build the topside and hullside electrical equipment, the electrical substation automation systems, and the E-Houses for the P-84 and P-85 FPSOs, with work to be carried out both abroad and in Brazil. The services will utilise ABB Ability™ System 800xA® and IEC 61850 substation automation technologies.

GOKTEPE GAS DISCOVERY

The Goktepe-3, which was drilled by the Abdulhamid Han drillship, has discovered gas. The discovery which holds potentially 2.6 Tcf of gas, will be developed via subsea wells tied back to FPU2 which is part of Sakarya Phase 3.

BESTLA OIL & GAS FIELD

The project’s subsea template installation and deck modules are expected before the end of June, with drilling activities slated to follow in Q3 2025. Tie-in and commissioning are scheduled for 2026.

ARAAM GAS CONDENSATE DISCOVERY

Saudi Arabia’s Ministry of Energy announced that Saudi Aramco has made a gas and condensate discovery at the Araam-1 well located in the Eastern Province. The well produced 24 million standard cubic feet per day (MMscf/d) of gas and 3,000 barrels per day (bpd) of condensate on test.

The Importance of

in the Energy Industry INTEGRITY

The manufacturing, energy, and infrastructure sectors are most dependent on critical assets and their management.

Asset integrity and asset integrity management are top priorities for energy companies which seek operational excellence and at the same time safe and efficient operations.

Effective asset management solutions help the energy industry, as well as other assetheavy industries, to boost the reliability, safety, and efficiency in operations as demand for energy continues to grow and governments are doubling down on energy security.

Proper asset integrity management systems and practices assure that offshore rigs and turbines, onshore processing facilities, producing and refining assets, pipelines, and wind and solar plants operate smoothly and efficiently, and failures are prevented.

Asset Performance Management Market Keeps Growing

In 2024, the global asset performance management market was valued at $3.6 billion, according to estimates by Global Market Insights (GMI).

Over the next decade to 2034, the global market for asset management is expected to grow by a compound annual growth rate (CAGR) of 10.7 percent, mostly driven by the rise of predictive maintenance and Internet of Things (IoT) technologies.

Predictive maintenance to help minimize downtime will be one of the growth drivers. Others include increased focus from companies on operational efficiency and cost reduction, adoption of IoT sensors and smart devices for real-time monitoring, and the integration of AI and machine learning for advanced analytics and insights.

Challenges could arise from the high initial implementation costs and resource requirements, and from issues with data integration across legacy systems, according to the report by Global Market Insights.

Market intelligence and advisory firm QKS Group expects the asset performance management market to rise at a 12.20 percent CAGR through 2030.

AI Opens New Chapter in Asset Performance Management

With the advance of data technology and AI, the industry has entered a new chapter where AI-driven models and tools are the new growth frontier, according to QKS Group.

Solutions in the asset performance management industry are transitioning from reactive maintenance to AI-driven predictive and prescriptive frameworks. The manufacturing, oil and gas, renewable energy, and utilities have started to prioritise systems that enhance asset reliability, reduce downtime, and optimise lifecycle costs.

As asset infrastructure ages and sustainability mandates increase, enterprises are adopting more tools to ensure asset integrity to balance operational resilience with capital efficiency, QKS Group says.

“APM is no longer just about maintenance - it’s a strategic lever for operational excellence. The fusion of IoT, digital twins, and machine learning is enabling real-time asset health monitoring, transforming how industries mitigate risks and maximize ROI,” commented Akaash R, Senior Analyst at QKS Group.

Energy Customers Unlock AI Potential for Asset Performance Management

Service providers and major technology companies are already offering AI-enabled or driven asset performance management tools and solutions.

Amazon Web Services (AWS), for example, has an offering of a cloud-managed, softwaredriven patented architecture for Industrial Asset Management platform—Shoreline AI.

Shoreline AI has implemented its solution for a Top 5 American multinational energy company with more than $200 billion in annual revenue and with thousands of locations in the United States. The organization uses a diverse range of machines in the production process, such as reciprocating compressors, engines, motors, tankers, pipeline, tanks, and valves. By using predictive maintenance strategies in an APM solution, the customer aimed to enhance equipment reliability and uptime, optimize maintenance costs, and improve safety and compliance of its assets. Additionally, the customer aimed to facilitate data-driven decision-making, thereby reducing operational costs and improving overall efficiency, AWS says.

Shoreline AI also has an Emission Leak Detection solution, which generates immediate notifications and the precise location of leaks and emissions such as methane or leaks of Volatile Organic Compounds (VOCs).

Norwegian energy giant Equinor has adopted condition-based maintenance (CBM) enabled by SAP Asset Performance Management.

“Equinor wanted to progress from condition monitoring to condition-based maintenance,” said Tom Naastad Svennevig, lead engineer at Equinor.

“The primary purpose of condition-based maintenance for us is to provide confidence for continued safe operation and avoid disruption,” Svennevig added.

“We believe that several degradation mechanisms we had in the past can be detected automatically, and actions being taken without human intervention.”

Equinor believes that the move to conditionbased maintenance would result in reduced administrative burdens and increased overall efficiency, automatic updating of asset information across all relevant components, seamless ingestion of sensor data from field systems, and empowering maintenance teams to act swiftly and effectively, minimizing downtime and preventing potential equipment failures. The new approach is also expected to lead to seamless scaling to accommodate additional equipment and assets, SAP says.

Malaysia’s national oil and gas company Petronas is standardising and improving the APM systems across its diverse business units, with GE Vernova’s cloud deployment easing harmonisation and migration as the Malaysian firm moves to Cloud Asset Performance Management.

According to GE Vernova, the expected outcomes include seamless integration with SAP S/4HANA, enhanced system performance, and standardised architecture, leading to better operational efficiency and reduced total cost of ownership (TCO). The project is aimed at ensuring technical compliance, improved user satisfaction, and robust cybersecurity, ultimately supporting Petronas’ digital transformation strategy.

APM solutions are being used in the renewable energy sector, too.

IBM bought late last year Prescinto, a provider of asset performance management (APM) software-as-a-service (SaaS) for renewables. Prescinto’s capabilities use AI to enable advanced monitoring, analytics, and automation to streamline renewable energy operations and manage clean energy and storage assets.

Prescinto’s asset performance management capabilities include employing open-source protocols and a data governance layer for data capture, as well as monitoring features for centralised visualisation of assets with high-definition maps, real-time monitoring, and custom alerts. Prescinto also uses AI to identify losses, visualise data trends, and offer recommendations to increase performance, IBM said.

Power Factors, a renewable energy management suite (REMS) provider, launched last year AI-powered applications designed to drive operational efficiency and performance optimisation for renewable energy across the asset lifecycle.

“Yesterday’s technology won’t solve tomorrow’s challenges. That’s why we’ve developed these state-of-the-art products to empower renewable energy leaders across wind, solar, and battery energy storage systems (BESS),” said Abilash Krishnan, Chief Product Officer at Power Factors. 

The Tools Are Ready; the Standard Is Set — Time to Rethink Inspection

Visual inspection is a core component of asset integrity management. Despite advances in remote technology, many inspection practices still rely on physical mobilisation to verify external conditions.

External degradation accounts for approximately 35–45% of asset failures. These include corrosion under insulation, coating damage, and impact-related deterioration—most of which are detectable through visual methods when appropriate access and technology are available.

On a typical offshore asset, visual inspection accounts for 60–70% of the total integrity workload. That equates to 10,000–20,000 manhours over a 5-year cycle, with thousands of individual visual checks many of which could be completed from onshore with the right tools. This inefficiency doesn’t reflect

the importance of the task; it reflects a lack of innovation in how we execute it.

GDi’s Remote Visual Inspection 2.0

GDi’s Remote Visual Inspection (RVI) 2.0 provides a method of delivering structured, desktop-based visual inspection using digital capture techniques and 3D photogrammetry. It enables visual assessments to be performed onshore, while retaining traceability, repeatability, and compliance with inspection effectiveness standards.

Vision - Anomaly Tags applied to a 3D model

Here’s how it works:

1. Digital Capture

High-resolution imagery is captured using photogrammetry or other scanning techniques, documenting the external condition of the asset in ful l detail.

2. 3D Model Generation

Captured data is processed into a photogrammetry-based 3D model, allowing inspectors to navigate, zoom, and view elements from multiple angles entirely from a desktop environment.

3. Desktop Inspection

Trained integrity engineers conduct structured visual assessments using the model. Observations are recorded visually and textually in a fully auditable format. While feature registration is not required for RVI, the model environment allows high confidence in location context and damage tracking.

4. API 581 Effectiveness Ratings

Where image quality and access allow, inspections can be formally closed out using API 581 inspection effectiveness levels (e.g., B or C level). For mechanisms such as general corrosion, coating breakdown, and deformation, this is increasingly viable.

5. Targeted Workpacks

Where RVI alone isn’t sufficient, it informs physical follow-up work only where it’s needed reducing scope, risk, and cost.

Credibility Built In

One of the most common concerns around remote inspection is whether it meets the required standard for integrity decisionmaking. API 581 helps answer this by allowing definition of inspection effectiveness across five categories, from A to E, based on surface coverage. The effectiveness rating for RVI is based on robust version of Table 5.9 to align with the expectations of a visually dominant inspection.

Category A is considered Highly Effective, reserved for 100% external surface coverage using high-resolution tools. While typically aligned to advanced NDT, in exceptional RVI conditions where full, clean, and unobstructed views are achieved, it may be approached.

Category B, or Usually Effective, represents over 75% external surface coverage, with surfaces mostly clean and only minor visual obstructions. This is where high-quality RVI typically operates when scan quality and lighting are excellent.

Category C is deemed Fairly Effective, covering 50–75% of surfaces with partial obstruction from insulation, paint, or structural elements.

Category D describes Poorly Effective inspections, with less than 50% coverage and uncertain visibility due to large blind spots or access issues.

Category E is Ineffective, where no reliable inspection has occurred, or the technique cannot detect the damage mechanisms of concern.

RVI 2.0 can credibly achieve Category B close-outs for general corrosion, coating breakdown, and deformation when supported by structured workflows, high-res scans, and clean models. Even where partial access or visibility limits surface coverage, Category C remains a valuable threshold, enabling confident planning decisions and informed campaign strategies.

API 581 reinforces this by tying inspection effectiveness to Consequence of Failure (COF). For low-consequence systems, a C-level inspection can be an efficient, standards-compliant route to close-out. For medium to high-consequence systems, B-level or higher may be more appropriate, aligning with a higher risk threshold.

In both cases, RVI 2.0 brings clarity and control. Where higher effectiveness cannot be achieved, the method still plays a pivotal role informing precisely where further action is needed and helping teams focus resources where they matter most. This transforms RVI from a backup option to a proactive engine of modern integrity strategy.

Why It Matters

Quantitative analysis of implementation across multiple offshore assets has shown that RVI 2.0 can reduce visual inspection workloads by 65–75%, particularly in areas involving repeatable and low-complexity features. Workpack generation and planning can also be accelerated by up to 50%, thanks to improved pre-inspection insights and seamless integration of digital workpacks.

There are also additional measurable benefits that position RVI 2.0 as a strategic inspection tool:

• A decrease in offshore risk exposure, driven by fewer access requirements and reduced POB,

• Structured, auditable records that support long-term degradation tracking and regulatory compliance,

• Improved prioritisation of physical inspection and NDT tasks, based on clearer data from pre-screened models.

RVI 2.0 introduces a methodical, standardsaligned approach to onshore visual inspection, backed by API 581 effectiveness logic and enabled by modern digital tools. Its application addresses both the operational inefficiencies and the technical expectations of contemporary integrity programmes.

By digitising what has traditionally been a manual, offshore-first activity, RVI 2.0 allows inspection teams to deliver faster, safer, and more targeted insights without compromising on quality or compliance.

The integration of RVI 2.0 into integrity strategy reflects a natural progression in the industry’s shift toward remote, data-driven operations. Its continued adoption will likely become a defining factor in how future inspection programs are delivered and managed. 

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THREE60 Energy’s Robust Approach to Subsea Asset Integrity

With a strategic vision for end-to-end energy solutions, Aberdeen-headquartered THREE60 Energy expanded its capabilities in 2023 and 2024 through the acquisitions of Flexlife and Samphire Subsea.

This move marked the formation of THREE60 Subsea, a dedicated service line specialising in lifecycle management of flexible pipes and umbilicals, as well as integrity solutions for operated assets, particularly in mature basins like the North Sea. The group now offers a powerful blend of engineering expertise, proprietary technology, and a track record in asset integrity innovation.

At the heart of THREE60’s subsea offering lies a simple but crucial principle: asset integrity begins at the design stage. While acronyms like FEED (Front-End Engineering and Design) and DDE (Detailed Design Engineering) are commonly associated with early-stage planning, they also form the foundation for long-term integrity management. Design determines the theoretical lifespan of each component, creating a benchmark for performance and degradation.

However, integrity doesn’t end at design; it continues through manufacturing oversight, where equipment is verified against specification and non-conformances are addressed. Installation is another defining moment, where proper procedures, meticulous documentation, and baseline surveys contribute significantly to the long-term integrity archive.

Once operational, systems are monitored continuously - tracking pressure, temperature, and fluid composition - with regular inspection and proactive anomaly response completing the lifecycle approach. This enables THREE60 to deliver both assurance and insight into subsea infrastructure health.

Case Study

A standout example of THREE60’s approach is an integrity project in the UK Northern North Sea, where a UK supermajor required evaluation of a two-piece riser system suspended between fixed platforms.

While operational metrics such as pressure and temperature remained within specification, annual annulus testing, vital to monitoring riser health, was compromised due to restricted vent ports. This raised concerns about the outer sheath and potential corrosion of the underlying armour wires - which support the riser’s weight. If these wires fail, one by one, the riser could ultimately collapse under its own load.

THREE60 applied a design-led approach, mapping the asset’s history and evaluating key events using qualitative and quantitative methods. Using FlexScan® technology, deployed via Oceaneering’s Neptune system, the team scanned the compromised area to assess wire condition 0.6 metres below sea level. This data fed into a refined corrosion model and wider fatigue assessment.

A detailed fatigue analysis was performed using the original design criteria to maintain consistency with the initial approach. Load cases were submitted to the riser’s original equipment manufacturer (OEM), who performed localised analysis based on the scanned wire condition.

The results were encouraging: despite the flooded annulus, the riser showed a remaining life of 120 years of equivalent service. With a safety factor of 10, this equated to 12 years - well beyond the field’s cessation of production (COP). In addition to confirming regulatory compliance, the analysis avoided a potential riser replacement, estimated at around £15 million.

A fatigue hotspot was flagged within the end fitting termination areaan often overlooked but critical connection point. To address this, the operator mobilised MAPS, an electromagnetic stress measurement tool, which confirmed that the wires remained in serviceable condition.

This project highlights how THREE60 combines smart technology, engineering rigour, and deep expertise to deliver meaningful integrity insights. By targeting the most critical components and adapting inspection methods to suit the asset’s design and operational context, THREE60 helps operators maximise value and assurance.

In today’s offshore energy landscape, where assets are ageing and production is extended, integrity is more than compliance - it’s a strategic imperative. With THREE60, operators gain a trusted partner committed to the longevity, safety, and performance of their subsea systems. 

Expert Hose Management That Keeps Your Operations Running

Ensuring safety, reliability, and compliance through expert design, inspection, maintenance, and 24/7 support—onshore and offshore, across the UK and worldwide.

Effective asset integrity management of flexible hose assemblies for the energy, renewable, subsea and industrial markets requires a multi-faceted approach combining proper design, installation, regular inspections, maintenance, and the use of advanced technologies for recording all aspects of the hose and fittings. The focus should be on ensuring hoses are fit for their intended purpose, minimising risk, and preventing environmental or operational hazards which can lead to expensive downtime and potential injury.

PTS Services are experts in this field with many years of onsite experience we have the tools and the knowledge to keep your hoses and fittings in top condition. Our team

of BFPA certified technicians are on hand 24/7 to maintain, service and replace hoses whether your requirements are offshore or onshore and we have our dedicated hose vans available to travel to site.

With our inhouse hose register system we can record and manage all your hoses at your facility and advise on certification, service and replacement and plan to allow sufficient time to minimise any disruption. Every hose is tagged with a unique serial number recorded in our system to allow easy and quick identification and replacement in the event of an emergency we can have the hose manufactured and shipped with the minimum of disruption fully certified and ready to install when it arrives onsite.

With an extensive range of sizes and types in stock from various manufactures and fittings available in stainless, carbon steel and various exotic metals onsite you can be sure that we can look after your hose and fitting requirements from our facilities in Aberdeen and Newcastle and can offer support in the UK and around the Globe. 

Contact us at sales@pts-services.co.uk to learn how we can assist you.

Detect flaws early, preventing costly failures

Streamline workflows for improved efficiency

Ensure compliance and safety with industry standards

Expand Smarter, Integrate Deeper, Co-create Value

How Integrity Software is Evolving Within the Blue Digital Ecosystem

In today’s offshore and subsea landscape, the concept of asset integrity has evolved beyond traditional engineering and compliance models. Integrity is no longer an isolated discipline, it’s becoming an intelligent, connected layer within a broader blue digital ecosystem. One that seamlessly links data, systems, and stakeholders across integrated energy operations, subsea.

This modularity also supports mass adoption, as solutions can be adapted across multiple verticals, sites, operators, and maturity levels, delivering consistent value without unnecessary complexity.

This shift is redefining how companies like Elementz approach product thinking, strategic value creation, and long-term operational resilience. The prize for transforming as part of a wider digital ecosystem is significant:

• Subsea teams can operate with up to 25% more capacity, empowered by digital enablement and streamlined workflows.

• Subsea operations require 30% less effort and are twice as predictable, enhancing planning, execution, and responsiveness.

• Operating costs are more than 40% lower, enabled by automation, deeper system integration, and a trusted understanding of cumulative risk.

Expand Smarter: Rethinking Integrity Subsea

Traditionally, integrity tools have grown in response to immediate needs; reactive, feature-heavy, and often disconnected. But expanding smarter means shifting toward modular, purpose-driven development, where functionality is grouped into scalable, interoperable components.

Rather than bloating systems with underused tools, modern solutions are now focused on:

• Core usability and UX refinement to support frontline adoption.

• High-value feature bundles that solve specific operational problems (e.g. Visualisation, Risk, Automation).

• Expansions that enable targeted value, allowing teams to tailor solutions to their evolving needs.

Integrate Deeper: Building for Interoperability and Context

True transformation happens when software integrates deeply and seamlessly. Elementz recognises that in the Blue Digital Ecosystem, connectivity is currency. Rather than locking operators into closed solutions, deep integration encourages a modular, scalable model where integrity becomes an enabler of digital collaboration, not a bottleneck.

Modern integrity solutions are increasingly designed to:

• Eliminate integration barriers, with simplified APIs and plug-and-play connectors.

• Work seamlessly with enterprise systems like SAP, Documentum, Risk and Barrier management platforms.

• Sync with digital twins and analytics engines, creating a feedback loop between asset health, operational decisions, and long-term planning.

By embedding integrity data within these wider systems, integrity becomes a living, responsive function.

Co-create Value: Enabling Partner Built Intelligence

The third pillar of this strategy is built on a simple truth: value today is co-created. The next evolution of integrity software is not just technological, it’s collaborative. As solutions become more open and modular, the opportunity to co-create value with users, partners, and innovators becomes a strategic advantage.

This means:

• Tapping into AI agents and predictive analytics to generate actionable insights.

• Enabling customer-driven innovation through frameworks like Elementz’ Compass initiative that prioritise what matters most.

• Collaborating with OEMs, service companies, academic institutions and startups to develop plug-ins and extensions that bring mutual value.

Whether it’s anomaly recognition, inventory planning, or intelligent inspection workflows, the ability to adapt and co-develop is becoming central to how integrity platforms evolve and scale.

Framing the Future: Integrity as an Intelligent Layer

As integrity software integrates deeper into the blue digital ecosystem, its role expands. It is no longer just a system to monitor degradation or compliance, it becomes an intelligent, adaptive layer that supports decision-making, operational resilience, and sustainable performance.

In this future, integrity is not only about protecting infrastructure. It’s about unlocking smarter, faster, and more collaborative ways to manage it. When we expand smarter, integrate deeper, and co-create value, we move beyond basic compliance and into a world where asset intelligence is always-on, always-adaptive, and always-connected.

As the subsea sector embraces this transformation, Elementz stands ready to support, providing the tools, flexibility, and ecosystem connectivity needed to not only ensure safety and longevity, but to redefine how we work, decide, and collaborate across the integrated energy landscape subsea. 

Jason Brown, Elementz CEO

TESS HOSE MANAGEMENT

Advanced lifecycle maintenance for maximum uptime & safety

TESS Hose Management (THM) is an advanced hose maintenance system that includes customised software and hardware, expertise, processes, and a specially trained workforce. This system provides optimal hose lifecycle management, reduced maintenance costs, and increased uptime. TESS takes full responsibility for compliance with regulations and standards.

The cost of a hose failure

A hose rupture may cause the release of harmful substances, which may lead to:

• Downtime and operational shutdowns

• Hazardous incidents such as fire and accidents

• Environmental emissions

• Risk of injury and loss of life

• Stop in production and loss of revenue

• Damaged reputation

• Serious environmental damages

Survey and registration

Technical data and condition of every hose are up-loaded to the THM database.

Hose maintenance plan

Planned inspections and replacements, based on a risk assessment of each hose installation.

ID tag

Each hose has a unique ID for fast identification and ordering.

Cloud-based database

Cloud and mobile app for hose management and maintenance, with offline capability.

Hose replacement

Hose replacements are based on inspection result and intervals in the maintenance plan

Uptime secured by service

Our 24/7 Hose Support ensures that the correct hose is being delivered and installed.

Keith Robertson Director keith.robertson@tess-aberdeen.co.uk

CAN – Your Trusted Partner

“Integrity is doing the right thing, even when no one is watching”…

…a quote by author C.S Lewis that is equally a shared tenet of CAN Group.

Now in our 40th year of business, CAN continues to uphold a reputable standing in the asset integrity arena. Key to the success and sustainability of CAN are our people, our corporate competence and of course our CAN-do attitude to deliver our expert services and solutions to our clients - safely and with integrity.

Industries and technology have evolved significantly since our formation in 1986 when CAN pioneered industrial rope access in the North Sea. Fast forward to the present day, with many significant innovations and industry milestones achieved along the way, CAN’s agility and versatility to adapt to changing markets have ensured it maintains its position as an industry leading provider of independent and impartial asset integrity solutions.

Over the last 40 years, CAN has seen many changes in the North Sea. Some Operators and Service Companies alike have come and gone or merged and changed their name. The ever-cyclic oil price has created industry booms and enhanced revenues but conversely, barrel price crashes have brought challenges that have impacted many, with businesses having to react, often restructuring and downsizing their organisations to become fit for the here, now and future. Alongside this, the once shiny new platforms have aged, and managing the integrity of ageing assets comes with further cost challenges to owners and operators, and increased tax levies have resulted in tougher decisions being taken with

respect to asset viability. Through these times though, the one constant that has remained is CAN’s dedication to safety and our unwavering commitment to fostering long-standing Client relationships to assure them of an honest and reputable service; a trusted partner that can listen, advise, adapt and deliver. CAN firmly believes that when challenges come our Clients way, our open and honest relationships that we have forged over the years become even more important and integral.

Recently, we have seen a number of long-standing Operators accelerate decommissioning programmes which has resulted in the need to scale back operations and expenditure, but without any detriment to safety and asset integrity. This is where CAN’s expertise, expansive service lines, technology and ‘out of the box’ thinking adds further value by rebasing inspection and maintenance strategies and unlocking opportunities to optimise resources and reduce spend.

Where Integrity Meets Innovation

For example, ENGTEQ, CAN Group’s Engineering Business Stream, embarked on a full top-down cleanse of a Clients Integrity Management System following an accelerated decommissioning program on two of their North Sea assets. It quickly became clear that the inspection program, driven by the Risk Based Assessment (RBA) and Maintenance Management System (MMS) processes, were now no longer fit for purpose and as a result, ENGTEQ’s approach focused on a number of key areas: Re-running all RBA using an “RBA Lite” approach, reviewing & cleansing all Preventative Maintenance (PM) inspection routines within MMS, reviewing and re-risk ranking all Inspection Backlogs and Integrity related Repair Orders.

Risk assessment was at the heart of the entire exercise, taking into account a Hydrocarbon free inventory, the re-purposing of existing equipment for plug and abandon (P&A) activities and carefully tracking which equipment would be positively isolated, engineered down and cleaned. This safely removed unnecessary inspections and repairs from the program and optimised the regime, with focus remaining on safety critical scopes and the items of inventory required for P&A.

ENGTEQ’s solution-driven approach achieved a 70% reduction in planned pressure systems inspections for the remaining life of field of one asset, and 53% on the other. It also derived a more streamlined inspection strategy, with CAN’s Inspection team utilising a find & fix / find & arrest approach, and Potential Dropped Object sweeps for the out of service plant; reflecting the shift of the asset risk profile to prioritise the structural integrity.

Despite a reduction in Risk Based Inspection manhours, having further accountability of the wider asset inspection & maintenance plans presented opportunities for CAN Group to proactively identify and propose scopes that fell within our wider corporate competency which would typically have been conducted by ad-hoc or campaigned teams. Through upskilling and/or substituting personnel disciplines, scopes were absorbed within core teams, leading to a reduction in mobilisations (including 3rd party Vendors), which brought greater efficiencies and added value through using asset familiar personnel without any detriment to safety or integrity.

Integrity is truly at the core of CAN’s business, keeping sight of both plant integrity and the integrity of our services. Solutions-driven and always aiming to exceed client expectations, CAN Group is your trusted partner for asset integrity. 

Pipeline specialist STATS Group target European growth with key appointments

Pipeline technology specialist STATS Group (STATS) has announced a number of promotions and appointments as it gears up to extend its international footprint and capture increased market share.

Ryan Holt, who began his career with STATS in 2014 as a graduate engineer, has been appointed General Manager for UK and Europe and will focus on operations, strategy, and growth in the region.

His progress at the Aberdeenshireheadquartered business has seen Ryan succeed as a project engineer, lead project engineer, and project engineering manager before this latest promotion.

STATS Chief Executive Officer, Stephen Rawlinson, said: “Ryan has excelled at every role he has taken on and he understands the value

MR Group promotes Alex Munro to Global HSEQ Director

Integrated energy services provider MR Group has promoted Alex Munro to Global HSEQ Director, underlining the company’s unwavering commitment to safety, integrity, and operational excellence.

we place on building a strong and sustainable UK/European regional business by meeting our client expectations through the safe delivery of industry leading products and services.”

Also supporting STATS European growth strategy, the company has appointed Mike Kaiser as Business Development Manager, Europe.

Based in Emmen, the Netherlands, Mike will strengthen STATS’ Europe customer reach in the traditional oil and gas sector while developing opportunities in the emerging hydrogen and carbon capture markets.

Apache Corporation announces two key leadership updates for UK asset

Apache has appointed two key senior leadership positions in the UK to lead North Sea late life operations.

3t Appoints New Head of Net Zero to Lead UK Clean Energy Training Initiatives

3t, UK’s leading provider of training and blended learning solutions for high-hazard industries, announces the appointment of Dan Taylor as its new Head of Net Zero.

Since MR Group’s acquisition of rig intake and inspection experts ModuSpec early last year, UK-based Alex has played a key role in developing and embedding critical HSEQ frameworks across the organisation – which also includes global training provider Well Academy and well engineering specialists WellSpec. In parallel, Alex has delivered HSEQ expertise across multiple client projects.

“Alex has demonstrated outstanding leadership, professionalism, and technical expertise,” said Duco de Haan, CEO of MR Group. “His appointment as Global HSEQ Director reflects the high level of trust we place in him to guide and evolve our HSEQ strategy globally.”

In his new role, Alex will continue to oversee the HSEQ capabilities delivered by ModuSpec to clients around the world – which include helping businesses foster strong occupational health and safety management systems, implement dropped objects prevention strategies, and enhance emergency response capabilities – while also providing strategic leadership and ensuring consistent governance across MR Group’s worldwide operations. 

McDaniel has been with Apache since 2001 and has served in operational and management roles with increasing responsibilities in the Permian Basin, Canada and Egypt. He previously worked at Chevron Petroleum Company.

Donald Martin has also joined the company as vice president, decommissioning. Martin has 20 years of operations and decommissioning portfolio experience, most recently as the head of decommissioning and projects at Spirit Energy E&P. He has also managed decommissioning at Canadian Natural Resources E&P.

“I am delighted to join the highly skilled and world-class workforce that safely maintains and operates our North Sea offshore assets,” said McDaniel. “I am looking forward to helping the team manage late-life operations and begin planning our decommissioning journey.” 

This new role is a strategically significant step for the future of 3t, as Dan will play a vital part in contributing towards the future of the UK’s energy workforce and accelerating the transition to a low-carbon economy.

Based at 3t’s hub in Manchester, he joins with a clear mission to lead the development and expansion of the company’s training courses and facilities, designed to support the UK’s netzero ambitions.

Under his leadership, 3t will further develop innovative training programmes across key areas, experienced engineers and new entrants in the gas, heating, electrical and renewables sector will have access to a range of clean energy technologies.

Paul Knowles, Senior Vice President – Training at 3t, said: “Dan’s appointment marks a major step forward in our commitment to enabling the energy transition with our high-impact training.

“His passion for sustainability, deep understanding of emerging technologies, and proven track record of driving impactful change make him an ideal leader for this critical role and 3t’s future in the sustainable energy industry.” 

In April, Greg McDaniel was appointed senior vice president, international assets, and will manage UK operations in addition to his role as country manager for the company’s Egypt asset.

Verlume Appoints Canadian Business Development Agent

Verlume, the world leader in subsea batteries and power management systems, has appointed Valor Ocean Technologies as its first business development agent in Canada.

The partnership follows the successful offshore deployment of three Verlume Charge systems in Canadian waters and signals a strategic expansion to meet growing market demand. Based in Halifax, Nova Scotia, Valor Ocean Technologies (formally known as ValorBPS) is a leading provider of advanced ocean technology systems, serving energy, defence, and scientific customers across North America. Headquartered in Halifax, Nova Scotia – with an additional office in Ontario – their team supports operations from the Atlantic Coast to the West Coast. Leveraging Canada’s world-class capabilities in ocean science, robotics, and offshore energy, Valor Ocean Technologies will lead efforts to grow Verlume’s presence and customer base across key markets. 

Ashtead Technology Appoints Andy King as QHSE Director

Ashtead Technology, a leading provider of subsea technology solutions to the global offshore energy sector, is pleased to announce the appointment of Andy King as QHSE Director.

Andy will oversee the group’s QHSE strategy, ensuring the highest standards of safety, compliance, quality and operational excellence across all international operations.

With a wealth of experience in QHSE leadership, Andy has most recently held senior positions at Helmerich & Payne and Harbour Energy, where he was instrumental in driving high-performance teams and achieving critical business objectives. 

Centurion Expands Global Leadership Team

Centurion Group, a global leader in the supply of specialist rental and services to a range of critical industries for complex, challenging and remote locations, is pleased to announce three senior appointments, strengthening Centurion’s global leadership team.

Adrian Hart joins from RSK Group as President of Centurion’s UK & Europe region, effective 18 June 2025, Gary Mawer joins from Scottish Water as Group Operational Efficiency Director, effective 30 June 2025 and Chris Gindl joins from Perma-Pipe as President of Centurion’s Canada region, effective 19 May 202

These new hires represent a significant milestone for Centurion, as it continues to invest and strengthen its senior management team as part of its continued transformation into a multi-industry rentals and services business. 

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IT/Communications | English | Exact Globe, Exact Synergy, Office 365, VBA programming, SQL server and related tools

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The OGV Jobs Board connects energy professionals with the latest opportunities across oil, gas, renewables, and engineering. Continuously updated, it offers a streamlined platform for job seekers and employers to post roles, discover talent, and grow careers—leveraging OGV’s trusted industry network across the global energy sector.

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Gwynt Glas secures site in The Crown Estate Leasing Round 5 Auction

EDF Renewables UK and ESB have successfully secured the rights to develop the Gwynt Glas Floating Offshore Wind Farm in the Celtic Sea through The Crown Estate’s Leasing Round 5. This project has the potential to generate up to 1.5 Gigawatts (GW) of renewable energy while bringing significant benefits to communities across South Wales and South West England.

The Gwynt Glas project has been selected through a competitive seabed tender process which follows more than three years of engagement with a range of key stakeholders to inform the best approach.

As part of the tender process, Gwynt Glas submitted proposals for developing the wind farm, alongside plans for maximising socio-economic and overall social value opportunities. The project will have the potential

TotalEnergies

to deliver green energy to millions of homes and contribute to the UK and region’s green economy, subject to the relevant environmental assessments.

Matthieu Hue, CEO of EDF Renewables UK, said, “I am absolutely delighted to announce that we, together with our project partner ESB, have secured preferred Bidder status with The Crown Estate for an Agreement for Lease as part of the Round 5 Leasing Process.

“We look forward to further developing the Gwynt Glas offshore wind farm, helping the UK maintain a market leading position in floating wind and recognising the important role that floating wind can play in the UK’s ambition towards reaching net zero.”

Jim Dollard, Executive Director at ESB said, “ESB, in partnership with our colleagues in EDF Renewables, is delighted to have been successful in The Crown Estate Round 5 seabed allocation in the Celtic Sea. The Celtic Sea is of strategic importance to ESB given its location adjacent to Ireland and the opportunities to develop a floating offshore project in what we believe to be an ideal area bodes well for our ambitions to develop a portfolio of floating offshore wind projects in Ireland and UK to contribute to the net zero plans for both countries as well as those of ESB.”

The Gwynt Glas project represents a key part of EDF Renewables UK’s strategy to grow its renewables business in the UK and contribute towards energy security and the climate crisis. With three offshore wind farms already operational in UK waters, the introduction of Gwynt Glas into the company’s development pipeline provides an excellent opportunity to leverage the group’s experience of building France’s first floating offshore wind farm. For ESB, Gwynt Glas is an important part of its growing offshore wind portfolio across Ireland and Great Britain as the organisation pursues its Net Zero by 2040 carbon emissions strategy.

The necessary development and consenting activities will now progress in accordance with current UK Government guidelines which will include comprehensive stakeholder consultation and determining the project’s size, turbine location, and installed capacity. The consenting process is expected to take three to five years with the wind farm potentially becoming fully operational in early 2030s. 

wins 1GW German wind auction

TotalEnergies has secured the rights to develop a 1GW offshore wind area in Germany’s North Sea following a competitive auction run by the Bundesnetzagentur.

The French energy major submitted the winning bid for the N-9.4 plot through its subsidiary North Sea OFW One GmbH in a process that attracted multiple zero-subsidy offers, triggering a dynamic bidding round.

The final price of €180,000 per megawatt means TotalEnergies will pay a total of €180 million for the 1000MW site.

The auction was held under section 20 of the WindSeeG law, covering areas that have not undergone central pre-examination.

Only one bid was awarded a contract, according to the decision published on 16 June 2025.

The award will be considered officially published on 23 June 2025, in accordance with the Renewable Energy Act.

“I congratulate our member company TotalEnergies on its auction success! Total Energies has secured a development portfolio of 7,5 gigawatts, making it the largest developer of offshore wind farms in Germany,” said BWO Managing Director Stefan Thimm.

“The results of the auction for site N-9.4 clearly demonstrate how significantly the risks for offshore wind developers have increased in recent years due to geopolitical tensions and supply bottlenecks.

“The current auction process no longer reflects economic realities. In addition to mandatory overplanting, these include rigid implementation deadlines and the associated penalties,” said the Managing Director of the German Offshore Wind Energy Association.”

He added: “These risks are reflected in the significantly lower auction proceeds compared to previous years and only two zero-cent bids.

“A bilateral Contract for Difference, or CfD for short, is necessary in parallel with the long-term power purchase agreements in order to secure the long-term attractiveness of the German market for investors." 

OWGP

officially assumes the role of Industrial Growth Plan Delivery Body marking a new era for offshore wind

The Offshore Wind Growth Partnership (OWGP) has formally assumed its new role as the Delivery Body for the Offshore Wind Industrial Growth Plan (IGP).

The announcement was made this morning (Tuesday) at Global Offshore Wind 2025 by Jane Cooper, OWGP Director and Deputy CEO of RenewableUK, who said:

“In December 2024, the Offshore Wind Industry Council (OWIC) appointed OWGP to take on the role of IGP Delivery Body.

“I’m proud to announce that OWGP has now officially assumed this responsibility. With the continued support from members of OWIC we will work together to deliver the ambitions set out in the Industrial Growth Plan, ensuring targeted, strategic investment that strengthens the UK’s offshore wind supply chain and drives long-term sector growth.”

Sophie Banham, OWIC’s OWGP Sponsor and Board Observer; UK Business Development Manager at Equinor said:

“The £34.6 million in funding provided by OWIC so far has been instrumental in driving a diverse range of initiatives and high-impact projects.

“We are proud to support OWGP as it takes on the role of IGP Delivery Body, and we remain committed to working closely together to ensure the UK maintains its global leadership in offshore wind development.”

As the IGP Delivery Body, OWGP will facilitate alignment of efforts across industry, government, and other stakeholders, ensuring investments are impactful. OWGP will regularly update the Plan to meet the demands of an ever-changing, highly competitive, global market.

Since the appointment was made last year, OWGP has moved quickly to scale operations and strengthen delivery, working closely with industry partners and stakeholders to build a framework that will enable it to deliver on its expanded remit.

This includes strengthening its internal capabilities with the recruitment of senior industry leaders to fill three interim roles critical to the implementation of the IGP, an Industrial Strategy Manager, an Investments Manager, and a Supply Chain Development Manager.

Further process improvements have been made, with the implementation of a new application portal, Submittable, which will streamline the application process for prospective beneficiaries and increase scalability.

Tim Pick, Chair of the Offshore Wind Growth Partnership and Commissioner of the Clean Power 2030 Advisory Commission, stated:

“I am proud of the progress we’ve made in the last six months.

“OWGP’s new role enables us to facilitate improved collaboration across government and industry to accelerate the UK’s leadership in offshore wind and ensure that UK companies are positioned at the heart of this global opportunity.”

In addition to internal improvements, OWGP has been working closely with a range of key stakeholders to strengthen industry relationships and enhance collaboration across the sector.

A new IGP Strategy Board has been established with the remit to guide strategic direction and ensure cross-sector alignment on funding allocation for major supply chain investment. The Strategy Board includes membership from UK and devolved governments as well as various funding bodies that support the sector.

Several Strategy Board members including Great British Energy, The National Wealth Fund, The Scottish National Investment Bank, The Crown Estate and The Crown Estate Scotland have come together to work towards an integrated public and industry finance ecosystem that will support the growth of the UK’s critical supply chain.

In close collaboration with the Department for Energy Security and Net Zero (DESNZ) and OWIC, OWGP has established an investment pathway for Clean Industry Bonus (CIB) contributions under Allocation Round 7 (AR7) of the Contracts for Difference (CfD) scheme for generators electing to utilise it.

Recent market screening conducted by OWGP has identified over £3 billion worth of potential investment opportunities across 33 UK-based CIB-compliant projects, highlighting the significant impact that this funding route can accomplish.

“The IGP includes projects in identified growth priority areas with total value of £2.8bn”, notes OWGP Programme Director, Anil Sayhan.

“To enable that level of investment, we need to step up how our integrated support ecosystem operates. Together with our partners, we are determined to build a globally competitive offshore wind supply chain here in the UK.”

Backed by strong cross-sector collaboration and a clear strategic vision, OWGP is now primed to deliver on the IGP’s promise of a stronger, more resilient UK offshore wind supply chain. 

Ibama to issue Brazil’s 1st offshore wind licence for 24.5-MW pilot

Brazilian environmental regulator

will issue the country’s first preliminary licence for an offshore wind project, concerning a 2 4.5-MW project.

This pilot project, with an installed capacity of up to 24.5 MW, will be located off the coast of the Areia Branca municipality, Rio Grande do Norte. It is being developed by Senai RN, which plans to install two wind turbines, one of 8.5 MW and a second one of 16 MW.

Once up and running, the offshore wind plant will deliver its output to the Porto-Ilha artificial island and port in Rio Grande do Norte, used for exporting salt.

Senai RN noted that the test site aims to adapt offshore technologies to the Brazilian environmental conditions, promote innovation in the electricity sector, train local labour and boost the region’s economic, social and environmental development. 

IBAMA

Five energy sector lessons from Ukraine

Figures shared by the Ministry of Energy of Ukraine state that, during three years of war, there have been 63,630 instances of damage to Ukraine’s oil, gas, and energy infrastructure, including over 34,000 substations, distribution and transmission lines, 4,800 generation facilities, 23,000 gas facilities, and 1,400 heating facilities.

By the end of 2024, the total estimated losses to the energy sector were approximately USD 93 billion. Despite these challenges, the Ukrainian energy system continues to operate and has introduced new measures to enhance its resilience.

Here are several lessons that can be learned to improve European energy resilience against various threats:

Synchronisation of networks

As a legacy of the former Soviet Union, the Ukrainian power system was synchronised with Russia's grid network. Before the war, Ukraine had begun the integration process with ENTSO-E and was scheduled to synchronise in 2025.

In February 2022, Ukraine planned a test to disconnect from the Russian grid and operate in island mode for several days. The first day of this test coincided with the start of the war on February 24, 2022, however the Ukrainian TSO and ENTSO-E worked tirelessly to secure urgent synchronisation within three weeks. Currently, the Ukrainian grid is synchronised with the EU grid, and efforts are underway to extend cross-border capacity from 1.7 GW to 2.5 GW for emergency situations. Importing electricity from the EU has helped Ukrainian businesses avoid power cuts during major attacks on the energy infrastructure.

Lesson: Synchronisation and the interconnection of networks between neighbouring countries plays a crucial role in grid resilience and stability.

Cyber attack protection

There were numerous cyber attacks on Ukraine's energy infrastructure that predate the war. During the war, that number increased significantly, with DTEK, the largest private energy company, reporting over 300 million cyber attacks during the war. The Ukrainian TSO and its foreign partners are working closely to introduce new measures against such attacks. Efforts have been made to foster a culture of cybersecurity within the energy sector, including regular training and awareness programmes for employees to ensure they can recognise and respond to cyber threats.

Lesson: Strengthening cybersecurity is essential for resilience. Multi-layered security, regular updates, and promoting 'cyber hygiene' are critical components.

Diversification of oil and gas supply

Ukraine was previously  heavily dependent on oil and gas supplies from Russia, but currently, is more flexible in purchasing oil and gas, sourcing these commodities from EU partners. There are increasing contracts for LNG supply from the US and other markets, delivered via EU ports. Several projects are underway to enlarge cross-border capacity for gas supplies.

Lesson: Each country should diversify its energy resources and not rely on a single source of supply.

Vulnerability of centralised generation

Ukrainian power generation and heat supply are predominantly centralized, with large coal-powered plants, nuclear stations, and hydro power stations supplying electricity to multiple cities or regions. Most cities also have centralised heating. Russia targeted power plants, causing blackouts across entire regions, and in response, the Ukrainian government adopted a strategy to build decentralised generation, with numerous small power plants that are more difficult and more costly to destroy.

Additionally, there is a strategy to introduce smart grids. DTEK, which lost all its coalpowered plants, is investing in wind projects in Ukraine, which are less vulnerable to missile attacks.

Lesson: Decentralised generation can create a more stable and resilient power system than one reliant on centralised production.

Energy as a service and merchant PPAs

During the war, Ukraine lost two-thirds of its generation capacities. To support businesses, the government introduced significant incentives for importing gas and renewable energy generating equipment. This led many businesses to build generation capacities on their sites. Most operate independently and are not visible to the grid, but more companies are becoming active consumers, consuming part of the electricity and selling the rest on the market. There is growing interest in the 'energy as a service' model, attracting investments in new projects.

High demand for electricity has driven market prices up, making Ukraine's electricity DAM prices the second highest in Europe. Many renewable energy producers are selling electricity based on market prices, having suspended their FiT licences. IFIs are beginning to finance projects based on market prices and are considering introducing a Minimum Price Guarantee Platform to increase the bankability of projects based on merchant sales of electricity.

Lesson: While system resilience is crucial for many businesses, energy resilience for businesses is equally important. Energy as a service and merchant PPAs models have significant potential to enhance the resilience of individual businesses from disruption to their energy supplies. 

Want to know more?

Brodies LLP is a UK top 50 law firm with offices across Scotland, the UK and internationally. For more useful insight and details of our energy expertise visit brodies. com

Yaroslav Petrov, Brodies LLP

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Innovating Asset Integrity: Building a Resilient and Sustainable Future for the Energy Sector

In today’s rapidly evolving energy landscape, asset integrity is more critical than ever. As the world transitions to new energy sources—whether renewable or low-carbon—the pressure to maintain safe, reliable, and sustainable operations has intensified.

Asset integrity ensures that infrastructure, from offshore platforms to renewable energy facilities, remains operational and safe throughout its lifecycle. To meet these challenges, the energy industry is embracing innovation to safeguard assets while reducing costs and minimising environmental impact.

The Evolution of Asset Integrity

Traditionally, asset integrity in the energy sector relied on reactive approaches, where problems were addressed only after they occurred. Inspections, repairs, and replacements were done post-failure, leading to significant downtime and unplanned costs. However, with the energy transition, this model is evolving.

Today, asset integrity management is shifting to a more proactive and predictive model. Operators focus on identifying potential risks and degradation before full-scale failures occur. This shift is driven by regulatory pressures, safety concerns, and a need for more efficient long-term asset management.

Moreover, asset integrity isn’t just for oil and gas companies; renewable energy sources like wind, solar, and hydrogen now face similar challenges. With these technologies still maturing, robust asset integrity practices are essential for long-term reliability, especially as the energy sector integrates decentralised and variable power sources.

The Role of Innovation in Asset Integrity

Innovation has become the backbone of improving asset integrity in the energy sector. New technologies and methods are emerging to address the challenges of maintaining complex infrastructure while ensuring sustainability. These innovations are paving the way for more resilient energy systems.

One such innovation is advanced materials technology. The development of new materials and coatings that resist corrosion, wear, and fatigue is crucial to extending the life of assets. For example, anti-corrosion coatings are widely used in offshore and onshore installations. These coatings protect assets from environmental exposure, ensuring they perform optimally for longer periods and reducing maintenance costs.

Additionally, predictive maintenance has emerged as a key innovation. By integrating real-time monitoring and performance tracking, operators can predict when specific components will need attention, allowing them to intervene before issues arise. This approach not only prevents unplanned downtime but also reduces operational costs.

Another significant innovation is conditionbased monitoring. This technique regularly assesses the condition of critical infrastructure, enabling operators to make data-driven decisions about repairs and

replacements. By focusing on real-time asset health, condition-based monitoring increases the reliability of assets and cuts down on unnecessary maintenance activities, further reducing costs.

The Future of Asset Integrity in New Energy

As the energy industry continues to evolve, the future of asset integrity will be shaped by innovations that prioritise efficiency, sustainability, and resilience. One promising trend is the increased adoption of advanced diagnostic tools and performance optimisation software. These tools allow operators to assess asset health in real time and make more informed decisions about maintenance schedules.

Sustainability will also play a critical role in the future of asset integrity. As the global push for cleaner energy intensifies, maintaining assets with a reduced environmental footprint will become increasingly important. Innovations focusing on reducing emissions and energy consumption in asset management processes are already gaining traction. For example, some companies are exploring ways to power maintenance operations using renewable energy sources, further reducing the carbon footprint.

Moreover, as the industry shifts towards decentralised power generation—such as offshore wind farms, solar installations, and green hydrogen plants—the complexity of asset integrity management will grow. To tackle these challenges, collaboration among industry stakeholders and the development of standardised asset integrity practices will be essential.

Innovation is the driving force behind the evolution of asset integrity in the energy sector. Whether through the development of advanced materials, the implementation of predictive maintenance, or the use of condition-based monitoring, the industry is moving toward a future where assets are more reliable, sustainable, and cost-effective. As new energy technologies mature, maintaining and enhancing asset integrity will be key to the long-term success of the energy transition. With continued innovation, the energy sector is positioned to build a more resilient and sustainable future—one where asset integrity is fundamental to every operation. 

Authored by

Douae El Boukili Technical R&D Consultant

Aerospace/Mechanical Engineering

Oil and Gas Sector Sees Robust Contract Wins Across Logistics, Exploration, and Decarbonization

The oil and gas industry has seen a flurry of significant contract awards in recent months, spanning various segments from logistics and exploration to engineering, procurement, and construction (EPC) and even the burgeoning carbon capture and storage (CCS) sector. These deals highlight continued investment in traditional hydrocarbon production alongside a growing emphasis on decarbonization efforts.

In a substantial development in the North Sea, Aberdeen-based logistics and supply company ASCO secured a landmark ninefigure contract with an undisclosed energy operator, believed to be Spanish energy company Repsol. This five-year agreement, effective from July 1, 2025, is valued at approximately £150 million and encompasses ASCO’s full suite of integrated logistics services, including quayside operations, warehousing, materials management, and environmental services. The deal reinforces ASCO’s position as a leading logistics provider in the region, even as the industry navigates the transition towards renewable energy.

Meanwhile, TotalEnergies and QatarEnergy have expanded their exploration footprint in Algeria, securing the Ahara license, an onshore area spanning 14,900 square kilometers. TotalEnergies will operate with a 24.5 percent stake during the exploration and appraisal phases, with QatarEnergy also holding 24.5 percent, and Algeria’s national oil and gas company Sonatrach SpA retaining a majority 51 percent stake. This move builds on TotalEnergies’ existing presence in Algeria, which contributed significantly to its 2024 production.

In the realm of carbon capture and storage, Expro has secured a key contract to deliver integrated well testing services for a high-profile CCS project offshore the UK. Commissioned by the Northern Endurance Partnership (NEP), a joint venture between bp, TotalEnergies, and Equinor, Expro will appraise two wells in the Endurance reservoir for future CO2 storage suitability. This contract underscores the increasing importance of CCS in the UK’s decarbonization strategy and leverages Expro’s extensive experience in reservoir appraisal.

Looking at broader trends, the first quarter of 2025 saw a marginal decline in global oil and gas contracts by total disclosed value, reaching $33.33 billion compared to $39.43 billion in the previous quarter. However, high-value contracts, particularly from Maire, Sinopec, and Larsen & Toubro, helped cushion this downturn. Operation and maintenance contracts dominated, representing 48% of the total, with the upstream sector reporting the most awards. Asia led regionally in contract volume, followed by Europe and North America.

Looking ahead, the global offshore EPC contract award value is forecast to see a marginal 1% year-on-year boost in 2025, totaling $54 billion. This is driven by 53 greenfield and brownfield final investment decisions, although high supply chain costs and a softening Chinese oil demand are influencing project timelines. The Middle East, Africa, and the Americas are expected to be key drivers of offshore EPC activity.

Petrofac’s Asset Solutions division has also had a strong start to 2025, securing $500 million worth of scope expansions and new contracts across the UK, Europe, Middle East, Africa, Asia Pacific, and the U.S. These awards cover late-life asset management, decommissioning, and integrated services, highlighting the company’s growth in core markets and strategic expansion into new geographies.

ADNOC Gas has been particularly active, awarding $5 billion in engineering, procurement, and construction management (EPCM) contracts for the first phase of its Rich Gas Development (RGD) project. UK contractors Wood, Petrofac, and Kent were among the recipients. These contracts are crucial for optimizing and debottlenecking existing gas assets and unlocking new gas streams, aligning with ADNOC Gas’s strategy to significantly grow its earnings and production capacity.

Separately, Wood, through its joint venture with Tendrill International Sdn. Bhd, secured a five-year contract with Brunei Shell Petroleum Sdn Bhd (BSP) for brownfield engineering, procurement, and construction (EPC) services. This extends their established relationship in Brunei, where they will continue to deliver integrated, end-to-end projects across BSP’s offshore and onshore assets. Wood also secured approximately $100 million in contracts to design gas flaring reduction systems for major oil fields in Iraq, further demonstrating its commitment to sustainable energy solutions.

Finally, EnerMech was awarded a significant contract by ExxonMobil to provide a complete flowline decommissioning package for the Hoover Diana development in the Gulf of Mexico. This marks EnerMech’s first major decommissioning campaign in the region and involves integrating multiple service lines to safely remove hydrocarbons and prepare subsea flowlines for decommissioning. 

Expro Wins Well Test Contract for Major UK CCS Project

Latest contract extends Expro’s decade-plus support of the UK Carbon Capture and Storage (CCS) industry

Energy services provider, Expro, has secured a key contract to deliver integrated well testing services for a high-profile carbon capture and storage (CCS) project offshore UK.

This award follows soon after the industry’s much anticipated December 2024 award of the first ever carbon storage permit by the UK Regulator, the North Sea Transition Authority (NSTA), to the Northern Endurance Partnership (NEP) for the storage of carbon dioxide in the Endurance reservoir located off the North-East Coast of England.

Expro has been commissioned by NEP to provide critical services that will be needed to appraise two wells in the Endurance reservoir for future CCS suitability.

The production and injection testing of the Endurance aquifer will provide important information that will be used to characterize the reservoir as part of the East Coast Cluster field development plan. Expro will deliver operations using capabilities and technologies from its well testing, fluid sampling and analysis, and subsea business segments. To provide a fully integrated CCS appraisal solution, Expro has selected Baker Hughes to provide its electrical submersible pumps

(ESP) and Metrol Technology for Drill Stem Testing (DST), Downhole Data Acquisition and Wireless Telemetry Services.

The Endurance reservoir has the capacity to store up to 450m tonnes of CO2. It is regarded as critical to achieving UK Government CCS targets of 20-30 million tonnes of CO2 a year by 2030 and over 50 million tonnes a year by 2035.

Northern Endurance Partnership (NEP) is a joint venture between bp, TotalEnergies, and Equinor. It was formed in 2020 as the East Coast Cluster CO2 transportation and storage provider company, which will transport and store CO2CO2 emissions from the Teesside and the Humber industrial clusters.

The contract is expected to safeguard local jobs in the North-East of Scotland, reinforcing Expro’s long-standing presence in the region. The company’s well test team will be based at its regional center of excellence in Aberdeen, ensuring operations are delivered utilizing local expertise. In its commitment to regional economic development, Expro will also prioritize engagement with UK-based suppliers, helping to strengthen and sustain the national energy supply chain.

Expro has more than 20 years’ experience in supporting CCS projects around the world, including the Northern Lights project in Norway. The company also has a 50-year-plus heritage of supporting the energy industry in the North Sea.

Iain Farley, Regional Vice President for Europe and Sub-Saharan Africa at Expro said: “Our success in securing this contract for the Northern Endurance Partnership demonstrates Expro’s ability to use our reservoir appraisal and well test capabilities, that have traditionally been used for the development of oil and gas reservoirs, to help kick-off the carbon storage industry in the UK. Expro is proud of both playing a key role in helping to decarbonize the UK and in the confidence that the Northern Endurance Partnership has placed in Expro to successfully deliver this project.

“This contract win builds on the success of the integrated well testing services that Expro has also provided to Equinor for the Northern Lights CCS project in Norway. It also demonstrates our commitment to the UK’s CCS program and the opportunities it is expected to create for local employment, economies, and supply chains.” 

Bilfinger UK secures multi-million-pound contract to enhance UK Gas Distribution Network

Bilfinger UK has secured a multi-million-pound contract with Cadent to update critical elements of the UK’s largest gas distribution network. This 12-month construction project, set to begin in Q1 2025, will involve a multi-disciplinary approach encompassing civil, mechanical, and electrical & instrumentation (E&I) scopes.

Bilfinger UK has secured a multi-millionpound contract with Cadent to update critical elements of the UK’s largest gas distribution network. This 12-month construction project, set to begin in Q1 2025, will involve a multidisciplinary approach encompassing civil, mechanical, and electrical & instrumentation (E&I) scopes.

The project will be executed under a framework agreement for Capital Construction Services and will cover four sites: two in the North West of England, one in the Midlands, and one near Cambridge. The works are designed with the future in mind, incorporating elements that will allow for the transportation of hydrogen within the network by 2050. Some components will be semifuture-proof to accommodate this transition.

Ben Hill, Gas Framework Director at Bilfinger Engineering & Maintenance UK, commented: “By utilising joint resources from our engineering, automation, and production teams, we are well-equipped to deliver comprehensive solutions that meet the highest standards of safety, quality and performance.

“Our partnership with Cadent reflects our commitment to innovation, efficiency, and sustainability, and we look forward to continuing our collaboration to meet the challenges of net zero and securing the UK’s energy supply.”

Will Banks, Head of Commercial – Capital Delivery at Cadent, said: “We are excited to work with Bilfinger UK on this critical project.

Their expertise and commitment to safety and innovation align perfectly with our goals for the future of the gas distribution network.”

Cadent, the largest gas distribution network in the UK by size, number of assets, and customers, prioritises safety in all its operations. This project will integrate safety measures throughout its execution to ensure the well-being of all stakeholders. 

Oil and Gas Decommissioning Market: A Dynamic Month in Re view

The global oil and gas decommissioning market has maintained its robust upward trajectory over the past month, with significant activity and ongoing discussions shaping its future.

While precise month-on-month figures for May 2025 are still being compiled, the broader outlook for the industry remains strong, propelled by the increasing maturity of offshore fields and an evolving regulatory landscape.

Projections continue to signal substantial growth in decommissioning expenditure. Recent reports from May 2025 indicated an anticipated US$45 billion to be spent on offshore decommissioning projects within the next five years. This represents an almost 8% year-on-year growth, with spending expected to climb from US7.0 billion this year to more than US10.3 billion by 2030. The market’s healthy performance stems from a growing number of deserted wells and increased investment in managing inactive oil and gas infrastructure.

Topside removal projects are gaining considerable traction, highlighting a shift toward the more complex and visible phases of decommissioning. Companies are actively forging strategic partnerships and

collaborations to bolster capabilities, share expertise, and address the multifaceted challenges inherent in decommissioning. Furthermore, efforts to expand geographical presence through acquisitions and new project developments are clearly evident. Asia, in particular, stands out for its rapid growth in decommissioning activities, with projects underway in Australia and India, alongside planned initiatives in Thailand.

The UK North Sea remains a focal point for decommissioning. With 22 UK fields ceasing production in 2024, and approximately 12% of active UK fields expected to cease production in 2025, the demand for decommissioning services continues to intensify. Companies like EnQuest are advancing their decommissioning campaigns, including the Heather topsides removal slated for 2025.

The North Sea Transition Authority (NSTA) consistently engages with the industry on decommissioning strategy, prioritizing costeffectiveness and exploring the potential for repurposing existing infrastructure.

Innovation remains a critical driver within the decommissioning market, with a strong emphasis on enhancing efficiency, safety, and environmental outcomes. Events such as the SPE Well Decommissioning Conference held in Aberdeen this June underscore the industry’s commitment to knowledge sharing and identifying future opportunities. A key area of technological focus is well plugging and abandonment (P&A), which, as the most costly phase of decommissioning, is driving the development of more efficient and environmentally sound techniques. The National Decommissioning Centre (NDC) continues to leverage its marine simulator for scenario planning, trialing new offshore technologies, and derisking decommissioning programs in virtual environments, thereby optimizing operations and assessing environmental impacts.

Despite this positive momentum, the decommissioning market faces persistent challenges. The high cost and complexity of decommissioning, especially for larger, deeper water platforms, remain significant hurdles, demanding highly engineered solutions and extensive planning. The regulatory environment is also continuously evolving, with recent legal decisions, such as that involving Nobel Oil E&P North Sea Ltd v NSTA, highlighting the intricate legal landscape and the imperative for robust decommissioning programs to comply with regulatory requirements. A critical challenge, particularly here in the UK, is managing the workforce transition as oil and gas production declines. A recent Robert Gordon University report warned of potential job losses unless urgent action is taken to sustain the offshore energy workforce and facilitate the transfer of skills to emerging sectors like offshore wind. The industry also faces scrutiny regarding its environmental impact, which is fueling demand for more sustainable decommissioning practices, including efficient material disposal and recycling.

In summary, the oil and gas decommissioning market is experiencing a period of intense activity and transformation. The past month has underscored its growth trajectory, the increasing importance of strategic collaborations, and the continuous push for technological innovation. However, effectively addressing the interconnected challenges of cost, regulatory compliance, and workforce transition will be crucial for the industry’s future success and its contribution to the broader energy transition. 

ExxonMobil lets decommissioning contract for Hoover-Diana developments

The specialist service company will deliver a complete flowline decommissioning package for the Gulf of Mexico assets.

ExxonMobil has let a decommissioning contract to EnerMech for the Hoover-Diana development in the Gulf of Mexico.

The contract scope includes decommission of the subsea flowlines which will include flushing, pigging, and filling the lines to safely remove hydrocarbons and prepare for decommissioning, according to a release issued on behalf of EnerMech June 16.

The work scope includes flushing of the umbilical, pipeline flushing, and seawater fill operations for the subsea flowline loop, as well as nitrogen flushing

via subsea vessel, coiled tubing services, and final seawater filling for the Northern Diana flowline. Multiple service lines will be required for this operation, including coiled tubing, pressure pumping, chemical services, filtration, separation, and pipeline gauging.

Hoover and Diana fields lie about 160 miles south of Galveston, Tex. Diana is sited mostly within East Breaks bloc ks 945 and 989 in 4,800 ft of water. Hoover lies in Alaminos Canyon blocks 25 and 26. The fields were discovered in 1990 and successfully appraised in 1997. 

AF Offshore Decom secures Heerema decommissioning gig

Decommissioning specialist AF Offshore Decom has been awarded a contract by Heerema Marine Contractors for the onshore reception, dismantling, and recycling of a production platform from the UK sector of the North Sea.

The scope of work includes both the topside and jacket, with a combined weight of approximately 15,000 tonnes. According to the current schedule, the topside and upper jacket are expected to be delivered to the company’s facility in Vats, renowned as one of the world’s most environmentally friendly dismantling facilities, in 2026. The remaining jacket section will be delivered in 2027. 

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Duty of Care through Technology and Expertise

Nicola Reith, General Manager, Scotland

ATPI is the trusted partner to the international energy industry, delivering expertise and solutions to 170+ countries worldwide. Naturally, this takes us into far reaching and diverse social and geopolitical environments, highlighting the importance of a proactive and responsive approach to duty of care. Between clients and regions, duty of care is ever evolving, so our support is always bespoke to the varied needs of our clients and the country of travel.

When travel and international policy moves fast, complacency isn’t allowed. Instead, we apply a continuous approach to ensure that our operational and technological solutions are always developing as the world does, adapting to client and industry needs per location. This is where a personalised approach is critical to fully understand a client’s business and what kind of support we can provide to them across the organisation.

As General Manager, Scotland, I am directly responsible for critical operational tasks including the quality of the services we deliver to clients regionally, how we manage and allocate our internal resources, and how we can do our best to ensure all client operations are of the highest standards possible. Consistent across each of these responsibilities though is my obligations to the wellbeing and duty of care for our clients and their traveling team members.

We are proud of our commitment to putting people first, always prioritising the safety, security, and wellbeing of clients and staff. Between addressing concerns surrounding travel safety, security, and operational efficiency, ATPI ensures that our people-led priorities remain at the forefront of our global strategy.

CrewLink

Supporting our duty of care processes is CrewLink. Emerging in response to industryspecific demands and the intricate challenges of energy travel, CrewLink allows users to plan and manage travel more efficiently. A travel management tool, CrewLink not only provides

greater operational efficiency and control but also establishes a foundation for more costeffective travel management processes.

From a duty of care perspective, CrewLink empowers organisations to navigate the often challenging and dynamic landscape of crew travel logistics, providing adaptable and bespoke insights for an industry where precision and responsive are paramount to workforce wellbeing.

With real-time crew tracking, an integrated communication hub, crew wellbeing support, and crisis response coordination, CrewLink has several critical features to monitor crew movement, ensure they have direct communication with support lines for rapid response to unexpected events, and can monitor their wellbeing through fatigue and rest periods.

A holistic service, CrewLink combines operational support with duty of care responsibilities.

North Sea Case Study

One of our long-standing clients, an international E&P company, has been partnering with us for over 20 years, utilising our extensive duty of care services. This ongoing relationship is built on shared values of transparency, accountability, and mutual trust. Rather than a traditional vendor-client dynamic, the client values a true partnership, aligned with the collaborative ethos we uphold at ATPI.

With travel across continents, including throughout Europe and Africa, the client utilises our team to help shape and inform its travel management strategy, alongside its duty of care approach to the workforce. They know that they have our experts on hand to help them focus their travel strategy.

Since joining ATPI, I have worked closely with the client and seen our dedication to duty of care in full demonstration. As part of the emergency response team that supports the client as and when they need assistance, I have seen first-hand the benefits of what our team can do. In one emergency situation in the North Sea, we worked closely alongside the clients’ Specialist Response Team to guarantee the safe onward travel of its crew.

By having people on the ground and available for all support requests, combined with our innovative technology platforms, we can create and cater bespoke emergency response services to handle any and all situations that arrive locally and across the globe. 

WHEN INTEGRITY MATTERS... SO DOES EXPERIENCE

Integrity management services:

Pipeline inspection

Our approach to asset integrity is rooted in decades of technical expertise and proactive risk management F micro-defects to major de team of engineering exper to keep your flexibles in lin

At The Impulse Group, we d the box on asset integrity –of the issues before they be problems, flagging vulnera and prioritising what matte Whether

Asset monitoring

Maintenance and repair