OGV Energy Issue 96 - OE Digital Transformation

WHAT'S INSIDE

Welcome to the September issue of ‘OGV Energy Magazine’ where this month we are exploring the theme of ‘Digitalisation’ and we are very excited as it is our largest issue of the year for the energy sector’s biggest UK energy event at Offshore Europe in Aberdeen!

A big thank you to our front cover partner GDI - An Oceaneering company and you can read all about how they are helping their clients to ‘Find the signal in the noise’ on pages 4-5.

In this bumper 60 page issue, we are also delighted to welcome contributions from Cegal, J&S Subsea, Three60 Energy, Tess, Elementz, Envizion, Petrasco Energy Logistics, PD & MS, Rosen, Mysep, Exceed Energy, GQS, Kranji, STATS Group, Intervention Rentals, OPITO, Brodies and ATPI

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, US and Australia, along with industry analysis and project updates.

Thanks as always to our corporate partners the Energy Industries Council, Leyton, Infinity-Partnerships, Elemental Energies and Archerthe 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. Warm regards, Dan Hyland

Integrity in the Digital EraFinding the Signal in the Noise

In asset integrity management, the problem is rarely a lack of information. Across the global energy sector, vast amounts of data are being collected every day - inspection readings, anomaly records, corrosion rates, condition monitoring results, and operational history. In theory, this should make decision-making faster and more precise. In practice, it often has the opposite effect.

The challenge for many operators is finding the signal in the noise - identifying which of the thousands of data points actually require action, which can safely be deferred, and which indicate developing risk that must be addressed before it impacts safety, production, or compliance.

This challenge is being amplified by the changing operational landscape:

• Ageing infrastructure demanding more frequent and targeted interventions

• Budgetary pressure limiting headcount and offshore access

• Increasing regulatory demands for traceability and documented justification

• Operational complexity across multi-asset portfolios and extended supply chains

At the same time, the expectation on integrity teams is not simply to maintain the status quo but to actively extend asset life, minimise unplanned outages, and deliver this with greater efficiency than ever before.

This is where many traditional integrity approaches show their limitations. Scaling resource to meet rising demand can only go so far before cost, complexity, and diminishing returns set in. What is needed is not more effort, but more focus - transformative tools and processes that allow existing teams to work at maximum efficiency, cutting through the noise to act where it matters most.

GDi, an Oceaneering Company is committed to providing exactly that. As a technologydriven company grounded in engineering expertise, our focus is on building systems that streamline integrity workflows from planning to closeout, enabling operators to do more with less - not by adding people, but by removing the friction that slows them down.

Focusing Efforts Where They Count Most

GDi’s Vision platform is built to restore flow across the integrity cycle. By integrating planning, execution, anomaly management, and reporting into a single environment, Vision enables operators to cut through the noise and focus effort exactly where it matters.

Our approach is defined by six capabilities that work together to deliver faster, better decisions with less wasted resource.

1. Statistical Risk Assessment (SRA): From Engineering Data to Probabilistic Insight

GDi’s SRA module applies proven statistical methods to your asset data - including historical inspection records, design parameters, and corrosion rates - to calculate time to failure for individual components.

Using mathematical techniques, SRA converts a qualitative likelihood estimate into a quantified probability of failure (PoF). This shifts planning from recurrence-based intervals to genuinely risk-driven inspection strategies.

Integrated within Vision, SRA creates inspection programmes that are statistically defensible, operationally efficient, and aligned with recognised methodologies such as API 581.

Why it matters:

• True risk-based planning using quantifiable models

• Reduced inspection scope without loss of coverage

• Justifiable deferrals with full audit traceability

• Greater confidence in asset life predictions and budgeting

2. Automated Workpack Generation: Targeted, Data-Led, and Offshore-Ready

Powered by the Oceaneering’s Inform PredictTM algorithm, GDi’s workpack engine analyses historical inspection data to determine the optimal distribution of inspection at a test-point level.

Inform PredictTM pinpoints the highest-priority locations based on degradation history, design context, and operational conditions. Each test point is plotted on the 3D asset model and linked to its plot plan location, so offshore teams can navigate directly to the inspection site and complete tasks in the most efficient sequence.

The result is an execution-ready workpack that combines engineering precision with offshore practicality.

Why it matters:

• Focuses inspection on highest-risk, highest-value locations

• Removes unnecessary low-priority inspection

• Provides visual and plot plan references for easy access

• Improves offshore efficiency and reduces downtime

• Delivers the most efficient inspection programme possible

3. Remote Visual Inspection (RVI): Insight Without Offshore Burden

RVI is fully integrated into the Vision workflow - not treated as a workaround, but as a recognised, auditable inspection method.

RVI scans are planned, executed, reviewed, and closed out entirely within Vision by our team of competent senior inspectors. Findings are traceable, supported by photographic evidence, and linked to follow-up work where required. This allows operators to progress inspection scope without waiting for shutdowns or mobilising full offshore teams.

Why it matters:

• Progresses inspection without bed space or shutdown dependency

• Maintains technical assurance and compliance

• Reduces MAH exposure and offshore logistics cost

• Shortens inspection-to-decision timelines

4. Visual Campaign Planning: Building Workable Execution Logic

Where RVI can’t finish the job, offshore inspection success depends on more than defining scope - it requires execution logic that works in the field.

Using the asset’s 3D model, Vision enables planners to group work by zone, access type, and permit boundary, bundling tasks to minimise unnecessary movement and duplicated access. Campaigns can be modelled and adjusted before mobilisation to eliminate clashes and optimise sequencing.

Why it matters:

• Reduced offshore time and cost

• Fewer access and permit conflicts

• Improved integration between inspection, maintenance, and scaffolding

• More predictable campaign delivery

DIGITAL TRANSORMATION

Registration within Vision ensures every component, from major equipment down to test point, is uniquely identified, fully traceable, and linked to its complete condition and inspection history. This guarantees that no item is “off the radar” and that all records are tied to the correct location, function, and operational context.

Records are structured, searchable, and visually attached to their related equipment within the 3D model. This eliminates the inefficiency of chasing files across different systems or static documents and provides decision-makers, auditors, and operational teams with instant access to current, validated information.

Why it matters:

• Reduces wasted time locating and validating data

• Improves internal governance and oversight

• Ensures complete and accurate component registration

• Speeds up audit and compliance reporting

5. Structured Anomaly Management: Finding the Signal in the Noise

Anomalies can overwhelm even the most capable integrity teams. Without effective triage, urgent issues risk being buried among routine or low-impact findings.

GDi’s anomaly management process is designed to separate the signal from the noise.

Anomalies are classified at the point of capture using consequence-led logic, defect type, and degradation rate. This enables automated prioritisation - routing high-consequence findings for immediate review and grouping low-risk items for bundling or deferral.

Reviewers work with full context - historical data, design details, images, and comparable cases - ensuring decisions are both consistent and auditable.

Why it matters:

• Ensures the highest-risk issues are addressed first

• Reduces backlog by streamlining lowpriority reviews

• Improves consistency across reviewers and assets

• Maintains a complete, traceable record from detection to closeout

6. Up-To-Date Integrity Records: One System, One Source of Truth

Vision consolidates all integrity datainspection history, anomalies, workpacks, reviews, registration records, and supporting evidence - into a single, unified environment.

• Supports continuous improvement across inspection cycles

The Value of Clarity

The energy industry is continually under pressure to deliver more output with fewer resources, while maintaining safety, compliance, and profitability. In this environment, the organisations that will succeed are those that can extract maximum value from the data they already hold - and transform it into timely, confident, and defensible decisions.

GDi’s role is to make this transformation achievable.

We don’t simply digitise existing processes; we design and deliver systems that connect them - removing wasted effort, automating where it adds value, and keeping the focus firmly on risk and outcome. By doing this, we help operators reduce inspection backlog without compromising integrity, shorten campaign durations to improve offshore efficiency, and consistently prioritise the highest-risk issues for action. Additionally, we ensure the maintenance of clear, auditable records that are readily available for regulatory scrutiny.

The key is clarity. Clarity about where to act, clarity in how decisions are made, and clarity in demonstrating that those decisions are the right ones.

Effective integrity management relies on clarity rather than data volume. It enables teams to focus on the work that protects safety, preserves asset value, and meets operational targets.

The goal is to deliver clear insights that enable operators to move beyond managing noise and consistently focus on the critical signal. This is where effective digital transformation brings efficiency, safety, and performance into alignment. 

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Editorial Tsvetana Paraskova

COMMUNITY news

QHSE ABERDEEN Launches Specialist

ISO 27001 Training Service to Bolster UK Information Security

In response to the growing demand for robust information security frameworks, QHSE ABERDEEN today announced the launch of a new, dedicated ISO/IEC 27001 consultancy and training service. This new offering is designed to help UK organisations implement and maintain world-class information security management systems (ISMS) to protect against evolving cyber threats and meet critical compliance standards. With data breaches and compliance failures becoming more prevalent, ISO/IEC 27001:2022 has emerged as the international gold standard for managing information security risks. The new service positions QHSE ABERDEEN at the forefront of assisting UK businesses in achieving and retaining this essential certification. 

JMSL Strengthens Leadership and Expands Team to Drive Strategic Growth

JMSL has entered a new phase of strategic growth, building on the recent key appointments to its Advisory Board. These appointments bring additional industry expertise and insight to guide the company’s long-term direction and ensure it remains at the forefront of the energy sector.

Alongside this strengthened leadership, JMSL has established a new entity in the Middle East to expand its presence in key international markets. While pursuing opportunities abroad, the company remains firmly committed to its traditional roots in the UK energy sector, which it has successfully supported since its formation in 2003. JMSL continues to deliver high-quality manpower, project services, and fabrication expertise to its valued clients. 

Integrity HSE Expanding in Offshore Renewables

Integrity HSE has bolstered its renewable energy offering with the appointment of Tim Worth as a QHSE Advisor. Tim arrives from Sulmara, bringing with him a depth of experience in subsea operations, with particular emphasis on offshore wind projects.

His arrival aligns with a period of growing recognition for Integrity HSE, which has been shortlisted in the ‘Best Practice’ category at the Scottish Green Energy Supply Chain Awards 2025, a testament to their continued work in the lowcarbon sector.

Tim’s early professional background includes a distinguished spell in the Royal Navy, reflecting Integrity HSE’s active support of the Armed Forces Covenant. After leaving military service, he transitioned to offshore oil and gas, progressing to the role of Senior Wireline Supervisor at Expro. He subsequently held key QHSE-related positions at Helix Energy Solutions Group and SERIMAX, and more recently provided HSE support to Shell, focussing on drilling and well interventio. 

ATPI, the travel partner of choice to the global oil and gas and energy market, has retained its position as an industry leader through updated contracts with two of the largest offshore drilling contractors within the Americas.

Securing both contracts in quick succession, each deal is worth an 8-figure sum per annum and follows established relationships that have been in place for over 10 years. The updated terms for each contract will continue for the next five years.

Following the recent announcement of an 11% sales increase between 2023 and 2024, the confirmation of these two contracts has placed ATPI in a favorable position heading into the end of the US fiscal year. 

Well Academy recently supported a group of oil and gas professionals on the latest leg of their well control training journey – culminating in the successful completion of the IWCF Well Control in Design and Lifecycle Management course.

The delegates from Sasol began their training pathway in 2017 completing IWCF Drilling Well Control Level 2 and IWCF Well Intervention Pressure Control 2 courses. Well Academy delivered the courses, which provide a solid grounding in essential well control principles, in Johannesburg, South Africa and Temane, Mozambique respectively.

As their development progressed, the individuals advanced to IWCF Drilling Well Control Levels 3 & 4 and IWCF Well Intervention Pressure Control Levels 3 & 4. These courses were delivered both virtually and at Well Academy’s Apeldoorn training centre in the Netherlands 

Perth’s new Pulse Technology Hub has officially opened, offering a fresh approach to technology, collaboration, and industry growth. Founded by Obi Gjerde, Aston Ladzinski, Ian Grant, and Thrym Kristofferson in late 2024, the Hub was born from frustration with a lack of innovation in local companies.

Located in the city’s heart, Pulse combines a showcase gallery with a workshop to support new entrants and international firms entering the Australian market. At its grand opening, attended by senior industry leaders, the Hub was praised as a much-needed space for safe innovation, project support, and technology-driven transformation. 

Sasol achieves training milestone with Well Academy

Pulse Technology Hub Launches in Perth, Driving Innovation and Industry

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UK North Sea Energy Review

By Tsvetana Paraskova

The importance of the UK’s oil and gas resources, the state of decommissioning of the energy infrastructure offshore Britain, and new projects and contracts have featured in the UK North Sea oil and gas sector in recent weeks.

Offshore Energies UK (OEUK) responded to NESO’s Future Energy Scenarios report, which set out four possible pathways for the UK’s energy transition.

Energy efficiency, demand flexibility, infrastructure and energy supply, and switching to low-carbon technologies will be the critical enablers for success in the energy transition, the report said, noting that “Success along the route to 2050 depends on the choices made today.”

OEUK Market Intelligence Manager Ben Ward commented,

“This report makes one thing clear: the UK’s journey to net zero is becoming increasingly challenging, there is a need for an acceleration of the deployment of low-carbon energy sources in partnership with meaningful engagement with the public to shape the way we consume energy in the future.”

The North Sea’s natural gas and emerging carbon capture industry remain essential to powering the country and cutting emissions, according to OEUK.

“Hitting our climate goals is getting harder each year. The UK already has the expertise, experience and world-class supply chains present in existing industries to deliver on the energy transition,” Ward said.

“To achieve our climate goals we need to continue to support our homegrown energy sectors.”

Oil and gas will remain part of the UK’s energy mix “for a long time,” the UK’s Prime Minister Keir Starmer said during a meeting with US President Donald Trump in Scotland at the end of July.

This reinforces the messaging from Offshore Energies UK, the trade body representing a sector that is vital to the UK economy, OEUK said.

“We believe in a mix, and obviously oil and gas will be with us for a very long time, and that’ll be part of the mix, but also wind, solar, increasingly nuclear…” Sir Keir Starmer said.

“As we go forward, the most important thing for the United Kingdom is that we have control of our energy and we have energy independence and security,” the Prime Minister added.

David Whitehouse, Chief Executive of Offshore Energies UK, commented on the PM’s statements,

“It is good to hear this clear recognition from the Prime Minister that the UK will need a diverse energy mix and that oil and gas remain essential to the UK’s energy future. We’ve long said that this is not a choice between renewables or oil and gas – we need both.”

Whitehouse added, “If we are going to use oil and gas, let’s produce it here – responsibly, with lower emissions, and with all the benefits to jobs, taxes and growth that come from homegrown supply.”

The North Sea Transition Authority (NSTA) published its UKCS Decommissioning Cost

and Performance Update 2025 report, which found that the North Sea oil and gas industry is forecast to spend £27 billion on decommissioning between 2023 and 2032.

Decommissioning is a key activity for the UK’s upstream oil and gas sector, with operators spending a record £2.4 billion in this area in 2024. This is clear evidence that operators are dedicating significant resources to cleaning up their legacy.

The sector is in a pivotal 10-year period, with operators estimating they will commit £27 billion to decommissioning between 2023 and 2032 – more than half the total forecast (2025 onwards) cost of fully decommissioning the remaining UKCS scope, which now stands at £44 billion in 2024 constant prices.

This is a £3 billion increase in the estimate through 2032 from last year’s report, showing that all decommissioning activities have become more expensive. The increase is due to multiple factors, including decommissioning work being brought forward, inflation, higher day rates for rigs, and activities exceeding planners’ initial cost estimates.

While several companies are performing admirably and are in the top quartile for efficiency, many are struggling to keep costs under control, NSTA’s report found.

The activity with the greatest potential for cost savings is well plugging and abandonment (P&A), which is set to account for about half of total decommissioning expenditure. It is also the area causing the greatest concern, as too many companies are delaying well P&A work, NSTA said.

A backlog of more than 500 wells which missed their original decommissioning deadline has built up, while more than 1,000 wells will be due for P&A between 2026 and 2030.

“The supply chain should be able to count on well P&A as a reliable revenue stream which keeps them anchored in the basin until more service companies can transfer their skills to energy transition projects, such as carbon storage, which are now starting to materialise and create opportunities,” NSTA said.

Together with the decommissioning cost update, NSTA warned that operators must immediately start tackling their backlog of wells that are already due for decommissioning to stop rigs leaving the North Sea and prevent billions of pounds of additional costs for themselves and taxpayers.

“Operators face higher costs if they continue to keep the supply chain waiting for work, causing further reductions in rig availability as the rig -owners seek opportunities overseas,” the industry regulator said.

“They also risk fines as last year the NSTA opened its first investigations into missed deadlines – and more could follow.”

Pauline Innes, NSTA Director of Supply Chain and Decommissioning, said,

“The stark reality is that operators are running out of time to get to grips with the backlog as more contractors consider taking their rigs abroad, which damages the supply chain’s ability to meet demand and remain cost competitive. We need operators to rise to the challenge and use the supply chain before they lose it.”

group has been renamed NEO NEXT and becomes one of the largest producers on the UK Continental Shelf. The joint venture is owned by Repsol E&P Group with 45 percent and NEO UK with 55 percent, with a projected 2025 production of approximately 130,000 barrels of oil equivalent per day (boe/d).

“Our strategy can be summarised as “Resilience, Yield and Growth”: the combined company has much more scale and diversity and opportunities for cost consolidation and portfolio high-grading giving resilience despite the tough conditions in the UK,” said John Knight, Executive Chair of NEO NEXT.

The stark reality is that operators are running out of time to get to grips with the backlog as more contractors consider taking their rigs abroad, which damages the supply chain’s ability to meet demand and remain cost competitive

Separately, NSTA fined Chrysaor £150,000 for vent breaches at the Armada hub in the Central North Sea in 2022.

Chrysaor, which was acquired by Harbour Energy in 2021, blamed the breach on high winds preventing it from relighting the flare on the Armada platform which is 132 nautical miles East of Aberdeen.

In total, Chrysaor vented 370.046 tonnes at Armada from 1 January 2022 to 31 December 2022, exceeding its consent by 145.566 tonnes, or almost 65 percent.

“Reducing the emission of harmful greenhouse gases is vital, and the NSTA will continue to support industry in its efforts to reach net zero by 2050,” said Jane de Lozey, NSTA Director of Regulation.

“In the few cases where companies fail to comply with requirements, the NSTA will not hesitate in applying tough sanctions.”

NSTA will enhance transparency of company specific information in new policy following a consultation launched in 2024. The policy will see companies named when an investigation is opened into a suspected breach, such as exceeding production or flaring and venting consents or failure to decommission.

Previously companies were only named once a sanction was given. A decision has been made to publish names earlier as it was decided it was in both public and sector interest, NSTA said.

In company news, Repsol UK has completed the strategic merger with NEO Energy. The combined

“This company will also be very well positioned to choose both organic and inorganic growth. We will certainly look to be making more value accretive acquisitions.”

Serica Energy said in early August it continues to make progress on advancing future production opportunities. Subsea tie-in work on Serica’s 100-percent operated Belinda field is progressing well, and this new field will come onstream at the start of 2026.

Well-Safe Solutions has been awarded a multi-year contract by EnQuest. The firm scope, expected to generate revenue in excess of $45 million, will be executed using the Well-Safe Defender and consists of a minimum of 100 days of activity in 2026 and a minimum of 130 days in 2027.

The contract also includes options for further activity between 2028 and 2034, creating a multiyear strategic partnership and securing vital supply chain resources in the North Sea well into the next decade, Well-Safe Solutions said.

Shelf Drilling’s North Sea subsidiary has secured a new contract for its premium jack-up rig, Shelf Drilling Fortress, for operations in the UK Continental Shelf. The contract is for one firm well with an estimated duration of three months, and a total value of approximately $12 million. Operations are expected to commence in late August or early September 2025. The rig most recently concluded a contract in the UK in May 2025. 

Europe Energy Review

By Tsvetana Paraskova

The

official opening of Norway’s new Arctic oilfield, oil and gas discoveries and development plans, and the UK’s offshore wind allocation round featured in Europe’s energy sector in the past few weeks

Oil & Gas

The Johan Castberg field, Norway’s northernmost oilfield, was officially opened in early August by Norway’s Minister of Energy, Terje Aasland.

The field, which started up earlier this year, already produces 220,000 barrels of oil per day. Production is expected to continue for at least 30 years, field operator Equinor said.

The new field “creates great value and ripple effects and is important for Norway’s role as a reliable, long-term energy supplier,” the company added.

“This is a milestone for the petroleum industry in the Barents Sea. With Castberg on stream, the Barents Sea now has both our second largest producing oil field, our second largest gas field and the largest discovery being considered for development,” Aasland said in his speech to the FPSO crew right after the opening.

Kjetil Hove, Equinor’s executive vice president for Exploration & Production Norway, said, “We are well underway and have already made new discoveries in the area.”

Less than three months after coming on stream the Johan Castberg field was producing at peak capacity of 220,000 barrels of oil per day. Every three or four days, cargoes depart from Johan Castberg.

Vår Energi and its partners have made a gas and condensate discovery in the Vidsyn prospect in the Norwegian Sea. Preliminary estimates indicate that the size of the discovery is 25-40 million barrels of oil equivalent.

The licensees will now assess the discovery together with prospects in the area for a potential development tied back to existing infrastructure, the Norwegian Offshore Directorate said.

The Vidsyn discovery is Vår Energi’s third commercial exploration success so far this year.

The recent Goliat Ridge discoveries are being matured as a fast-track subsea development with flexibility to include potential future discoveries, and two appraisal wells are planned in the Goliat Ridge later this year, Goliat North and Zagato North, Vår Energi said.

The company is progressing around 30 early-phase projects accounting for net 2C contingent resources of around 600 mmboe and expects to sanction over 10 projects during 2025. Four projects have been sanctioned year to date, including Balder Phase VI, a fast-track development operated by Vår Energi that will contribute with high value production through the Jotun FPSO already in late 2026. Fram Sør, a subsea tieback development to Troll C, took a final investment decision in the second quarter, developing 116 mmboe gross resources, Vår Energi said.

TechnipFMC has been awarded a significant integrated Engineering, Procurement, Construction, and Installation contract by Equinor for its Heidrun extension project in the Norwegian North Sea.

For TechnipFMC, a “significant” contract is between $75 million and $250 million.

Energy data and intelligence provider TGS, in collaboration with Axxis Multi-client AS and Viridien, have announced the successful completion of the final imaging of OMEGA Merge, to deliver a single, seamless, and unified high-quality dataset across the Heimdal Terrace, Utsira, and Sleipner Ocean Bottom Node (OBN) multi-client surveys.

Spanning a total area of 3,700 square kilometres from the deployment of over 250,000 nodes and 9.5 million shots, OMEGA Merge is the largest continuous OBN dataset on the Norwegian Continental Shelf, TGS said. Energean and its partner INA – INDUSTRIJA NAFTE d.d. have taken Final Investment Decision (FID) for the development of the Irena gas field offshore Croatia. Energean has a 70 percent working interest in the project. The development plan is for a single platform tie-back to the existing infrastructure at the Izabela field. First gas from the Irena field is expected in the first half of 2027.

“The decision to invest in the development of the Irena gas field is another important step in advancing our strategy of strengthening domestic oil and gas production and ensuring Croatia’s long-term energy security,” Josip Bubnić, Operating Director of Exploration and Production at INA, said.

Low-Carbon Energy

Offshore Energies UK (OEUK) has proposed key reforms to accelerate offshore wind generation following the government’s publication of its Review of Electricity Market Arrangements (REMA).

The decision to take a national approach to pricing will encourage more wind energy investment to help the government hit its Clean Power 2030 targets and boost growth in the critical offshore energy supply chain, OEUK says.

OEUK’s analysis shows that to meet the goal of 95 percent clean power by 2030, the UK must deliver half of this target from offshore wind. This means at least 43 gigawatts (GW) of offshore wind capacity must be installed by 2030, but current projections fall short at just 35 GW. The next three Contacts for Difference

(CfD) rounds must therefore secure an additional 20 GW—equivalent to powering around 15 million homes, according to OEUK.

OEUK welcomed the government’s reforms to the CfD scheme or Allocation Round 7 for offshore wind.

“This new and pragmatic approach to planning, timelines and budgets is important for making Allocation Round 7 (AR7) a success,” said OEUK’s wind and renewables manager, Thibaut Cheret.

“It will enable fixed-bottom offshore wind projects without finalised planning permission to enter this year’s AR7 Contracts for Difference auction. OEUK is pleased the UK government has also followed our recommendations to expand Contracts for Difference (CfD) from 15 to 20 years to unlock investment and reduce cost to consumers.”

To get to the Clean Power 2030 goals, OEUK believes it’s critical the AR7 raises 8.4 GW of offshore wind capacity, which depends on working in partnership with industry.

The UK Government has shortlisted six projects to start negotiations to join the HyNet carbon capture cluster in the North West. These are Connah’s Quay Low Carbon Power, Essar Energy Transition Industrial Carbon Capture (EET ICC), Hydrogen Production Plant 2 (HPP2), Ince Bioenergy with Carbon Capture and Storage (InBECCS), Parc Adfer Energy from Waste Industrial Carbon Capture Project, and Silver Birch.

OEUK head of energy policy Enrique Cornejo, commented, “If we are to hit the UK’s net zero targets and keep our industries thriving, CCUS projects like this must move from plans to delivery much faster.”

Energy technology and oilfield services group SLB has been awarded a technologies and services contract for carbon storage site development in the North Sea by the Northern Endurance Partnership (NEP), an incorporated joint venture between bp, Equinor, and TotalEnergies.

NEP is developing onshore and offshore infrastructure needed to transport CO2 from carbon capture projects across Teesside and the Humber — collectively known as the East

Coast Cluster — to secure storage under the North Sea.

The project scope for SLB includes drilling, measurement, cementing, fluids, completions, wireline, and pumping services.

Another major energy services provider, Halliburton, has also been awarded a contract by the Northern Endurance Partnership (NEP)—to provide completions and downhole monitoring services for the carbon capture and storage (CCS) system.

Halliburton will manufacture and deliver the majority of the equipment required for this project from its UK completion manufacturing facility in Arbroath.

Statkraft, Europe’s largest generator of renewable energy, is to take forward plans for its Shetland Hydrogen Project 2, after agreeing a lease on a site owned by Shetland Islands Council.

in areas including Scotland, Devon, Greater Manchester, and Wales.

The Cydnerth project, which will support the expansion of the Morlais tidal energy scheme, has moved into its construction phase as work has begun on-site at Parc Cybi, Holyhead to strengthen the grid infrastructure for Morlais, a flagship tidal energy project run by local social enterprise, Menter Môn Morlais Ltd.

Backed by the North Wales Growth Deal and funding from both the Welsh and UK Governments, the £16-million Cydnerth project will future-proof Morlais by increasing its grid capacity from 18 MW to an eventual 240 MW.

This is an important and welcome step toward realising the full potential of Ynys Môn’s tidal resources and establishing the area as a hub for sustainable energy

Shetland Islands Council has settled a lease with Statkraft, which plans to build a green hydrogen hub and ammonia production adjacent to the disused Scatsta Airport.

The proposed scheme is an electrolytic hydrogen to green ammonia production facility of up to 400 MW, on land adjacent to the disused Scatsta Airport which is near the existing Sullom Voe Oil Terminal and Shetland Gas Plant.

Pulse Clean Energy has secured a £220 million green finance deal from a consortium of six international banks, marking one of the largest financings in the UK for battery storage infrastructure. This green financing will facilitate the construction of six ready-tobuild battery energy storage system (BESS) sites, including the conversion of existing diesel sites to BESS assets. It will also support the ongoing funding of nine sites already in operation or in late stage construction. These sites are strategically located across the UK

“This is an important and welcome step toward realising the full potential of Ynys Môn’s tidal resources and establishing the area as a hub for sustainable energy,” Andy Billcliff, Chief Executive of Menter Môn Morlais Ltd, commented.

The European Commission has approved an 11-billion-euro French scheme to support offshore wind energy in line with the objectives of the Clean Industrial Deal.

The measure will support the construction and operation of three floating offshore wind farms: one in the sea off the coast of Southern Brittany and two others in the Mediterranean Sea. Each windfarm is expected to have a capacity of around 500 MW, and to generate electricity equivalent to the annual consumption of 450,000 French households.

This measure will contribute to France’s transition towards a net-zero economy and reaching the renewable energy target set at EU level for 2030, the Commission said. The scheme was approved under the Clean Industrial Deal State Aid Framework (CISAF) adopted by the Commission on 25 June 2025. 

USA Energy Review

By Tsvetana Paraskova

The US industry faces contrasting outlooks for oil and natural gas production as oil drilling activity has slowed while the number of active rigs drilling for gas has increased over the past year.

Slowing Oil Activity

“The primary drivers of drilling activity in North America are commodity prices, corporate cash flows and capital allocation strategies, not government policies. And those factors have not, in general, incentivised management teams to pursue growth this year,” Ed Crooks, Vice Chair Americas at Wood Mackenzie, said in an analysis in August.

“Drill, baby, drill” may work well at political rallies and on social media. It is less of a winning message in boardrooms and in investor meetings.”

Despite US President Donald Trump’s ‘drill, baby, drill’ slogan, the number of active oil and gas drilling rigs has dropped since his inauguration, and since the summer of 2024.

The US Administration strongly supports oil and gas output, infrastructure expansion, and exports.

But companies base their investment and activity on commodity prices, cash flows, and capital expenditure strategies. These have not favoured a boost to US oil rig counts or a surge in production.

Despite reaching record output levels, US crude oil production has seen growth slow in recent months, amid lower oil prices and uncertainties about demand and markets in the second half of the year and early next year.

“Drill,

WoodMac reckons oil prices will be lower next year compared to 2025, while global oil demand is set to level off in the early 2030s. The energy consultancy sees US oil production levelling off before the peak in global oil demand.

Bullish Gas Outlook

In gas, the outlook is completely different. The AI-driven surge in power consumption will support higher gas-fired power generation, while LNG exports will continue to rise. These two key growth drivers will warrant higher gas production in the United States.

baby, drill” may work well at political rallies and on social media. It is less of a winning message in boardrooms and in investor meetings.

While the number of oil rigs sunk, the number of gas drilling rigs rose, suggesting that the current conditions in the US energy industry favour increased gas production but slower growth in US crude oil production.

The number of rigs drilling for oil in the US has dropped over the past year by about 14 percent, but the number of rigs drilling for gas has risen by 20 percent, according to estimates by WoodMac.

The contrast is most evident in key oil and gas producing basins, according to Ryan Duman, a director on Wood Mackenzie’s US Upstream research team.

The number of active rigs in the oil-focused Permian Basin has fallen by 44 this year, while the number in the Haynesville gas-producing shale play has risen by 10.

The trends reflect two contrasting outlooks—a more bearish one for oil and a bullish outlook for US gas production.

Wood Mackenzie expects that North America’s domestic gas demand plus exports will jump by about 33 percent over the next 10 years, from about 1.26 trillion cubic metres (tcm) in 2025 to about 1.67 tcm in 2035.

LNG exports are set to more than double, while data centres for AI and new factories are driving a surge in US electricity demand, with gas-fired plants playing a key role in meeting that increased demand, WoodMac says.

As a result of the bullish outlook on gas, US producers are signing supply agreements to deliver gas to power plants close to the producing centres.

Recent deals “mark a strategic turning point for Appalachian producers,” said Robert Clarke, Wood Mackenzie’s vice president of Upstream research.

These agreements signal the rise of a new asset class for Lower 48 shale gas: driven by data centre demand, adjacent to infrastructure, and supported by long-term contracts, Clarke noted.

Despite rising activity and new demand growth, most gas-focused companies have not moved yet to significantly hike investment.

“Some of the leading listed gas-focused E&Ps are restraining their spending and prioritising financial strength, because they still face pressure from investors to maintain capital discipline, cut borrowings and return cash to shareholders,” according to WoodMac.

Shale Offers Long-Term Strategic Advantage to US Supermajors

The shale basins, especially the high exposure to the Permian Basin, offer strategic advantages to the US supermajors ExxonMobil and Chevron, compared to their European rivals, say WoodMac’s Clarke and Luke Parker, Vice President, Corporate Analysis.

The shale resource is an advantage in a portfolio of a major international firm as it offers scale, the capacity to produce volumes in the longer term, and the flexibility to ramp investment up or down in response to price, WoodMack’s analysts reckon.

The consultancy expects Exxon and Chevron’s domestic shale production to continue growing despite an imminent peak in total US liquids production. Both majors have amassed huge Permian positions, and each has over 10 years’ running room in Tier 1 inventory at sub-US$45 WTI price breakeven cost at current rates of drilling. As the play matures, these leading players are intensifying efforts to reduce capital intensity, including through the use of AI.

Chevron’s Permian production is expected to jump by nearly 25 percent to above 1.2 million boe/d by 2030, when it will contribute around one-third of the company’s total output, according to Wood Mackenzie.

The aim thereafter will be on maintaining production around that level and maximising free cash flow generation.

The Permian basin is even more important to ExxonMobil as it contributes almost a third of 2025 volumes. Exxon’s output in the Permian is forecast to surge by 55 percent to 2.3 million boe/d by the end of this decade. This would be equal to BP’s total production, WoodMac says, expecting Exxon to hold that level through to 2040.

Other majors will not find easily available shale acreage to buy, if they wanted.

“Buying into US tight oil at scale at this mature stage of development seems unlikely,” WoodMac’s analysts noted.

High-quality opportunities aren’t obvious after sector consolidation, while buying into tight oil and its unique ecosystem in the past has often proved a costly mistake for outsiders.

US Gulf Coast Set for Major Gas Expansion

US Gulf Coast gas development is set to shape the future of the US gas market, according to Daniel Myers, Senior Research Analyst, North America Gas, at Wood Mackenzie.

The US Gulf Coast natural gas market faces unprecedented expansion, with demand projected to grow over 28 bcfd by 2050, Myers said in a report in July. The growth on the US Gulf Coast extends far beyond LNG exports, as power generation, industrial applications, and blue hydrogen development are set to account for more than 30 percent of expected demand increases.

The Permian and Haynesville basins emerge as critical supply sources supporting the US Gulf Coast regional expansion, each adding around 10 bcfd to Gulf Coast supplies over the long term, according to WoodMac. 

Middle East Energy Review

By Tsvetana Paraskova

The OPEC+ group plans to complete the 2.2 million barrels per day production cuts in September, earnings at Saudi Aramco were hit by the lower oil prices in the second quarter, but the world’s top crude oil exporter is bullish on global oil demand in the second half of the year.

The OPEC+ allies reaffirmed their “commitment to market stability on current healthy oil market fundamentals and steady global economic outlook,” OPEC said.

“The phase-out of the additional voluntary production adjustments may be paused or reversed subject to evolving market conditions. This flexibility will allow the group to continue to support oil market stability.”

Granted, the actual increase is likely to be lower than the headline figures suggest – as in previous months – due to the producers that are foregoing large output hikes to compensate for previous overproduction, such as Iraq, OPEC’s second-largest producer, for example.

The eight OPEC+ countries will continue to hold monthly meetings to review market conditions, conformity, and compensation.

With the output increase in September, OPEC+ will have unwound the biggest layer of cuts in recent years.

One final layer, of 1.66 million bpd, remains to be rolled back. Currently, OPEC+ plans to do so by the end of 2026.

However, if markets tighten due to sanctions, penalties, or additional crackdowns on Russian and Iranian oil exports, OPEC+ could step up and unroll these cuts sooner than expected, analysts say.

“We believe the group is finished with its supply hikes, as we move out of the stronger summer demand period and inventories start to rise,” ING commodities analysts said after OPEC+ announced the decision in early August.

“However, much also depends on what happens to Russian oil flows.”

Middle East Set To Become Second-Biggest Gas Producing Region

The Middle East is set to surpass Asia to become the world’s second-largest gas producer in 2025, ranking only behind North America, Rystad Energy said in new research and analysis.

Natural gas production in the Middle East has jumped by about 15 percent since 2020, and the future growth underscores the determination of regional producers to monetize gas reserves and develop export potential to meet global demand, the independent research and energy intelligence firm said.

The Middle East currently produces about 70 billion cubic feet per day (Bcfd) of gas. This is expected to jump by 30 percent by 2030 and 34 percent by 2035 thanks to significant developments in Saudi Arabia, Iran, Qatar, Oman, and the UAE. By 2030, the region will add another 20 Bcfd, equivalent to half

These are some of the most recent themes in the Middle East oil and gas sector, which also include rising investment in Oman’s oil and gas sector and the UAE’s ADNOC Drilling reporting record revenues and profit.

OPEC+ Proceeds with Output Hikes

The OPEC+ alliance decided in early August to increase their collective production in September by 547,000 barrels per day (bpd).

The eight countries implementing the 2.2-million-bpd cut – Saudi Arabia, Russia, Iraq, UAE, Kuwait, Kazakhstan, Algeria, and Oman – will have completed the rollback of all these output reductions in September.

of Europe’s entire gas demand as of today, Rystad Energy reckons.

This outlook hinges on Brent oil prices holding at $70 per barrel and oil-indexed gas prices hovering at the range of $7-9 per million British thermal units (MMBtu). If prices fall below $6 per MMBtu, new projects could be delayed, and expected volume growth by 2030 could slow, depending on the severity and duration of the price decline.

“About half of the 20 Bcfd new supply will meet rising domestic demand, particularly from industrial users, while the rest will be available for export,” said Mrinal Bhardwaj, Senior Analyst, Upstream Research, Rystad Energy.

“As more long-term gas contracts are signed and export volumes rise, the Middle East is on track to become a key energy hub for countries seeking stable and dependable sources of natural gas.”

Oil & Gas Drive Foreign Direct Investment in Oman

Foreign Direct Investment (FDI) in Oman surged to approximately $79.5 billion by the end of the first quarter of 2025, with inflows reaching $13.6 billion, up from $10.7 billion during the same period in 2024, preliminary figures released by the National Centre for Statistics and Information (NCSI) showed.

Upstream oil and gas remained the largest recipient of FDI, attracting $64.1 billion, or 81 percent of total investment, with quarterly inflows of $12.5 billion, according to the data.

The United Kingdom remained the largest FDI contributor, accounting for 51 percent of total FDI at $40.5 billion, followed by the United States with $20.3 billion, and Kuwait with $3.2 billion.

Saudi Aramco Books Profit Drop, Bets on H1 Oil Demand Growth

Despite higher oil production in line with the OPEC+ deal, Saudi Aramco booked a 19-percent drop in second-quarter earnings as

MIDDLE EAST ENERGY REVIEW

lower oil prices weighed on liquids realizations. Aramco reported a net income attributable to shareholders of $22.85 billion for the second quarter, down by 19 percent from the same period last year. The income also fell compared to the first quarter as Aramco’s average realized crude price was $66.70 per barrel in April to June, down from $76.30 in the first quarter and from $85.70 a barrel for the second quarter of last year.

The world’s biggest oil firm, however, remains bullish on the oil market in the second half of the year and in the long term.

ADNOC Drilling Company PJSC, said it delivered record-breaking performance across revenue, EBITDA, and net profit while maintaining strong momentum in shareholder returns and delivering regional expansion.

For the first half of 2025, ADNOC Drilling booked a record net profit of $692 million, up by 21 percent from the same period last year. Revenues jumped by 30 percent to $2.37 billion, EBITDA rose by 19 percent to $1.08 billion, and free cash flow soared by 67 percent to $727 million.

Market fundamentals remain strong and we anticipate oil demand in the second half of 2025 to be more than two million barrels per day higher than the first half

“Market fundamentals remain strong and we anticipate oil demand in the second half of 2025 to be more than two million barrels per day higher than the first half,” Aramco president and CEO Amin Nasser said.

“Our long-term strategy is consistent with our belief that hydrocarbons will continue to play a vital role in global energy and chemicals markets, and we are ready to play our part in meeting customer demand over the short and the long term.”

In the United Arab Emirates, Abu Dhabi’s ADNOC has announced its intention to transfer its 24.9 percent shareholding in OMV AG to XRG, its wholly-owned international investment company focused on gas, chemicals, and green energy.

ADNOC Drilling is expanding regionally in Oman and Kuwait, while Turnwell, ADNOC Drilling’s unconventional drilling specialist, reached new operational milestones in the second quarter of 2025 as it expanded its presence across the UAE’s onshore unconventional basins.

ADNOC Drilling also continues to embed AI, automation, and advanced analytics across its operations to enhance efficiency, safety, and reliability.

“ADNOC Drilling has consistently demonstrated its ability to grow in any phase of the energy cycle,” said Abdulla Ateya Al Messabi, ADNOC Drilling CEO.

“With high and visible cash flows, growing earnings and strong visibility of future returns, we remain confident in our ability to continue delivering long-term value to our shareholders.” 

Adnoc

Norway Energy Review

By Tsvetana Paraskova

Oil and gas operators offshore Norway have raised production in recent months and announced discoveries in recent weeks, while the Norwegian government moved to strengthen the supply chain in the domestic offshore wind industry.

“The results are affected by lower liquids prices, which were partially offset by higher gas prices and higher production,” Equinor said.

Equinor delivered a total equity production of 2.096 million barrels of oil equivalent per day (boepd) in the second quarter, up by 2 percent from the same quarter last year and above the 2.064 million boepd in the analyst consensus estimate.

“We are on track to deliver production growth in 2025 in line with our guidance,” Equinor’s chief executive officer Anders Opedal said in a statement.

“Strong operational performance and Johan Castberg reaching plateau are key contributors this quarter. In today’s volatile markets we stay committed to being a long-term energy provider to Europe.”

Strong Oil & Gas Performance

Norway’s energy major Equinor, partly owned by the government, reported earnings for the second quarter in line with analyst estimates as it boosted oil and gas production and reiterated its commitment to be Europe’s longterm energy provider.

Equinor booked an adjusted operating income, its closest metric of core earnings, of $6.53 billion for the second quarter, a decline of 13 percent compared to the same period of 2024. The result was in line with a companyprovided consensus estimate of 21 analysts.

The contract secures a substantial share of BASF’s natural gas needs in Europe. BASF uses natural gas both as an energy source and as a raw material in the production of basic chemicals.

Deliveries will start on 1 October 2025, Equinor said.

“Natural gas not only provides energy security to Europe but also critical feedstock to European industries,” Equinor’s Opedal said.

“I am very happy that our gas also supports BASF’s efforts to reduce their carbon footprint. Gas from Norway comes with the lowest emissions from production and transportation.”

Natural gas not only provides energy security to Europe but also critical feedstock to European industries

After less than three months in production, the Johan Castberg field in the Barents Sea reached a plateau on 17 June. The same month, an oil discovery estimated at approximately 9-15 million barrels was made in the area and can contribute with additional reserves for the field.

Moreover, Equinor and UK’s Centrica have signed a long-term gas sales agreement of 55 terawatt hours (TWh) of natural gas per year for a period of 10 years, demonstrating the importance of long-term gas supplies from the Norwegian Continental Shelf to support the UK’s energy security.

Equinor also confirmed its strategic partnership with BASF by signing in July a ten-year natural gas supply agreement, which will see an annual delivery of up to 23 TWh of natural gas over the period.

Another operator on the NCS, Aker BP, said in July that its field development portfolio was progressing according to plan, “with several projects even moving ahead of schedule.”

“Our robust balance sheet and solid cash flow generation enable us to navigate market volatility with confidence – while continuing to deliver attractive and resilient dividends to our shareholders,” CEO Karl Johnny Hersvik said.

Aker BP has also strengthened its North Sea portfolio with an agreement with Japex to swap a 10-percent interest in the Aker BP-operated Alve Nord development and a 3.5-percent interest in the Verdande development. In exchange, Aker BP will receive Japex’s Northern North Sea portfolio and a cash consideration of $14 million.

The effective date of the transaction is 1 January 2025, with completion subject to approval by Norwegian authorities.

Japex’s Northern North Sea portfolio comprises a 15 percent interest in the

Kjøttkake discovery (PL1182S), a 10 percent interest in the Kveikje discovery (PL293B/ PL293CS), and a 20 percent interest in PL1212S.

By increasing its stake in Kjøttkake to 45 percent and entering Kveikje with 10 percent, Aker BP strengthens its position in a high-potential cluster of discoveries, the company said.

Norwegian oil and gas operator DNO ASA has confirmed a gas and condensate discovery on the Vidsyn prospect, close to its producing Fenja oil and gas field, both within the Norwegian Sea licence PL586. DNO has a 25 percent stake in the licence, up from 7.5 percent prior to the recent acquisition of Sval Energi Group AS completed in June.

Preliminary estimates at Vidsyn put gross recoverable resources in the range of 25 to 40 million barrels of oil equivalent (MMboe) with a mean of 31 MMboe, above the predrill estimate range. The partnership, including Vår Energi ASA (75 percent and operator), considers the discovery commercial and sees a potential to unlock a larger volume in the licence.

Vidsyn is located just eight kilometres west of the Fenja field, which is tied back to the Equinor-operated Njord field facilities 35 kilometres to the northeast. Njord oil is exported by shuttle tankers while gas is piped to the market via the Åsgard Transport System.

New Strategy for Norway’s Offshore Wind Supply Chain

The Norwegian government unveiled in August a new strategy for the local offshore wind service and supplier industry. The government sees great opportunities for the domestic industry to support the local offshore wind sector and win contracts abroad.

In 2023, more than 800 companies, many of which with experience in the petroleum industry, had a combined turnover of NOK 44.6 billion, or $4.4 billion, up by nearly 30 percent from a year earlier, according to the government’s latest figures.

New projects both on the Norwegian continental shelf and internationally make authorities confident that the offshore wind supply chain has the chance to grow further.

Norway will not provide state support for offshore wind projects in the foreseeable future, but will contribute to the crucial startup phase of the supplier companies, Energy Minister Terje Aasland said.

Norway’s supply-chain companies are competing internationally because they have built

on world-class offshore expertise in the petroleum industry, Minister of Trade and Industry, Cecilie Myrseth, said.

The Norwegian supplier industry plays a key role in the low-emission economy, Myrseth added.

The Norwegian government has an ambition to allocate acreage for the development of 30 GW of offshore wind by 2040. This is almost as much as the entire Norwegian hydropower production today.

Sørlige Nordsjø II and Utsira Nord are the first steps toward achieving the offshore wind goal. Sørlige Nordsjø II will be Norway’s largest power plant in terms of installed capacity and will provide electricity equivalent to the consumption of about 450,000 households.

In May this year, the government announced a competition for project areas for offshore wind in Utsira Nord. Each project area may have an installed capacity of up to 500 MW of floating offshore wind.

To support the supply chain companies, Norway’s government pledged to facilitate regular calls for proposals and support competitions in a start-up phase. 

“Vidsyn is another exciting addition to our string of Norway discoveries,” said DNO’s executive chairman Bijan Mossavar-Rahmani.

“Together with Vår Energi, we will work hard to put it into production faster than is the norm in Norway.”

In another exciting discovery, Equinor and its partners have made a gas discovery in the Skred prospect close to the Johan Castberg oilfield in the Barents Sea. The well was drilled about 23 kilometres north of discovery well 7220/8-1 on the Johan Castberg field and 210 kilometres northwest of Hammerfest.

Preliminary calculations indicate the size of the discovery is 1.9 – 3.1 million barrels of oil equivalent. The licensees will now assess the discovery with a view toward a possible tie-in to the Johan Castberg field.

https://varenergi.no/

“Vidsyn is another exciting addition to our string of Norway discoveries”

DNO’s executive chairman Bijan Mossavar-Rahmani.

Australia Energy Review

By Tsvetana Paraskova

Australia’s major energy firms have strengthened their domestic operations and boosted oil and gas production while the federal government raised the clean energy targets.

Woodside and Santos Raise Output, Strengthen Portfolios

Woodside Energy has agreed to assume operatorship of the Bass Strait assets, unlocking potential development of additional gas resources, following an agreement with ExxonMobil Australia.

From completion, Woodside will assume operatorship of the offshore Bass Strait production assets, the Longford Gas Plant, the Long Island Point gas liquids processing facility, and associated pipeline infrastructure. Woodside and ExxonMobil’s equity interests in the assets and current decommissioning plans and provisions remain unchanged.

As operator, Woodside will take on the responsibility for asset planning and execution activities, pursuing a value maximisation strategy that targets further production and reliability improvements, the Australia-based company said.

“As a proudly Australian company, Woodside supports essential domestic energy needs in both Western Australia through the North West Shelf, Pluto and Macedon operations, and on the east coast through its equity participation in Bass Strait,” said Woodside EVP and COO Australia Liz Westcott.

“Taking operatorship of Bass Strait demonstrates Woodside’s continued commitment to meeting Australia’s domestic energy demand while maximising the value of existing infrastructure,” she said.

Woodside also reported quarterly production of 50.1 MMboe (550 Mboe/d) for the second quarter, up by 2 percent compared to the first quarter of this year.

“We delivered strong production of 50 million barrels of oil equivalent for the quarter from our diverse portfolio of high-quality assets. At the same time, ongoing focus on cost control has enabled us to lower our unit production cost guidance for 2025,” Woodside CEO Meg O’Neill said.

“Our announcement in April of a final investment decision to develop the Louisiana LNG Project positions Woodside as a global LNG powerhouse, complementing our established Australian LNG business and enabling us to meet growing global demand from a broader range of customers.”

Woodside also remains focused on delivering the Scarborough Energy Project for gas-toLNG on schedule and budget.

In May, Woodside had the floating production unit hull and topsides for the project connected. Scarborough is now 86 percent complete and on track for first LNG cargo in the second half of 2026, O’Neill said.

Another Australian energy major, Santos, said it had increased second-quarter production

to 22.2 mmboe, up 1 percent compared with the prior quarter.

Western Australia domestic gas production increased by 15 percent compared to the first quarter, driven by successful John Brookes well intervention campaign, steady production from Halyard-2, and strong reliability at Varanus Island, averaging 98 percent for the first half, Santos said in its Q2 results release.

As part of activities for the Moomba Carbon Capture and Storage (CCS) project, Santos executed a non-binding Memorandum of Understanding with the South Australian Government to explore CO2 import and pipeline infrastructure opportunities in support of CCS and low-carbon fuels ambitions in the Cooper Basin.

The Barossa LNG project is around 97 percent complete. The BW Opal FPSO (floating production, storage and offloading) vessel arrived at the Barossa gas field and was successfully hooked up to the subsea infrastructure. Final commissioning activities are progressing to plan. All scopes of work, including the Darwin LNG life extension activities, remain on track for first gas in the third quarter, Santos said.

“We continue to see very strong demand and premia for high heating-value LNG from projects such as Barossa and PNG LNG, as well as for reliable regional supply,” Santos managing director and CEO Kevin Gallagher said.

“Santos’ diversified LNG contract mix provides the flexibility to adapt to evolving market dynamics and capture value-accretive opportunities.”

Australia Raises Renewable Energy Target

While Australian firms look to boost gas production and supply domestically and globally, the federal government in July raised the capacity target in its Capacity Investment Scheme (CIS) from 32 gigawatts (GW) to 40 GW.

The CIS will help deliver the Australian Government’s target of having 82 percent renewable electricity by 2030.

The scheme has so far seen 6 oversubscribed, successful tenders launched, and it is on track to deliver 18 GW of generation and dispatchable storage projects.

The 8-GW capacity increase is set to incentivise investment in projects to deliver an additional 5 GW of storage and 3 GW of renewable power generation by 2030. A 3 GW boost to CIS generation was helped by the competitive nature of the tenders and falling costs of solar, the government said.

The uplift is expected to support investment of around US$13.6 billion (AUS$21 billion) in storage capacity. Investments of nearly US$34 billion (AUS$52 billion) are expected in solar and wind technologies.

More renewable generation and dispatchable projects will create jobs within local communities, support Australian supply chains and manufacturers, and help replace aging coal plants and support rising demand, the government says.

Australia should address the gaps and overlaps in emissions reduction incentives, speed up approvals for clean energy infrastructure, and create a resilience-rating system for all housing to meet its clean energy targets, the interim report of the Productivity Commission inquiry recommends. The Productivity Commission (PC) is the Australian Government’s independent research and advisory body on a range of economic, social, and environmental issues.

The report calls for reforms to the Environment Protection and Biodiversity Conservation Act, which is slowing down vital approvals without effectively protecting the environment. These reforms would introduce national environmental standards, improve regional planning, and set clear rules about engaging with local communities and Aboriginal and Torres Strait Islander people.

The interim report also calls for a greater focus on approvals for priority projects and recommends the Government appoint an independent Clean Energy CoordinatorGeneral to work across government and break through roadblocks. A specialist ‘strike team’ should also be established to ensure priority projects are efficiently assessed.

“Getting to yes or no quicker on priority projects would meaningfully speed up the clean energy transition,” said Commissioner Martin Stokie.

Renewables Surge and Remain Cheapest New-Build Power

The second quarter of 2025 saw record generation output from wind, grid-scale solar, and rooftop solar energy, the Australian Energy Market Operator (AEMO) said in its quarterly report.

Across the National Electricity Market (NEM), a warmer and sunnier start to the June quarter, combined with more new renewable generation capacity, saw record Q2 generation output in wind, up by 31 percent, grid-scale solar (+17 percent), and rooftop solar (+15 percent).

New all-time 30-minute output records were also set, with wind generation reaching 9,472 megawatts (MW) on 25 June, up 13 percent on the previous high. Grid-scale battery discharge surged 119 percent to average 162 MW, driven by 3,116 MW/6,415 MWh of new battery capacity since the end of Q2 2024, the market operator said.

Continued investment in new wind and solar has lifted renewables’ share of generation from 32 percent to 38 percent year-on-year for the quarter, said AEMO Executive General Manager Policy and Corporate Affairs Violette Mouchaileh.

In periods in June, isolated cold conditions and low wind conditions triggered spikes in heating demand and reduced wind generation. This led to a greater reliance on gas-fired generation and batteries to meet evening peak demand, AEMO noted.

“Ongoing investment in gas-fired power remains critical to generate energy during these periods of low wind or solar, or when storage reserves are depleted, and to support growing demand as our power systems transition,” Mouchaileh said.

Renewables remain the lowest-cost newbuild electricity generation technology, while nuclear small modular reactors (SMRs) are the most costly, according to the final 202425 GenCost Report by CSIRO, Australia’s national science agency, in collaboration with the AEMO.

Yet, rising construction costs in Australia and supply chain constraints for some technologies remain a challenge for reducing costs, the report found.

“The latest GenCost report released by the CSIRO today reaffirms the longstanding reality that renewables are the lowest-cost, and most practical option to transition Australia’s energy system,” said Anna Freeman, Clean Energy Council General Manager – Advocacy & Investment.

“The truth remains that renewables remain the lowest cost form of energy, even when taking into account the cost of firming these generation assets, including the costs of storage, transmission, and system security.”

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Rystad Energy forecast a cautious offshore rebound, with FPSO-based projects spearheading recovery. Floaters were expected to account for 41% of offshore sanctioning value between 2021–2023, surpassing fixed platforms and subsea tiebacks, as operators leaned into deep-water, cost-effective deployments.

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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.

MINA WEST GAS FIELD

The operating joint venture comprising of and KUFPEC announced a financial investment decision for the field development.

The Mina West gas field, located in water depths of approximately 250 metres, will be developed as a subsea tie-back to the existing infrastructure of West Delta Deep Marine (WDDM).

SHENANDOAH SOUTH SUBSEA TIE-BACK

A final investment decision has been announced with first oil expected to be reach in Q2 2028. The discovery which is estimated to hold around 74 million barrels of oil equivalent (P50 resources) will see the drilling and completion of two production wells. The wells will be tied back to the Shenandoah FPU using a 3.2km flowline and a dedicated riser.

AZERBAIJAN

SHAH DENIZ COMPRESSION PROJECT

SOCAR-KBR LLC has secured a contract to provide detailed engineering design solutions and procurement services for the SDC gas field project. The company was also awarded a contract to support the BP operated Sangachal Terminal Electrification (STEL) Project.

MERPATI FIELD DEVELOPMENT

Following the award of a Production Sharing Agreement for Block C in Brunei, EnQuest will now look to form a JV with Brunei Energy Exploration Sdn Bhd. Once established the JV will focus on the development plan for Merpati with the aim of reaching a final investment decision in 2027, and starting gas production in 2029.

GAJAJEIRA GAS AND CONDENSATE

Azule Energy has announced a gas discovery through the Gajajeira-01 exploration well, drilled by the Valaris 144 jack-up rig.

Preliminary estimated resources are about 1Tcf of gas and 100MMboe of condensate. Drilling operations will continue on the well targeting the Lower Oligocene LO300 interval.

AKKAS FIELD REDEVELOPMENT

Iraq has signed a new agreement with SLB to increase the production at the Akkas gas field in Al-Anbar province.

Schlumberger will be drilling new wells to achieve an initial production rate of 100 MMcf/d, and targeting a longer term production rate of 400MMcf/d.

SABRATHA GAS

PROJECT – A AND E

STRUCTURES

INTEGRATED FIELD DEVELOPMENT

A project management services contract has been awarded to Hill International. The scope of work includes detailed design to approve engineering on new infrastructure and upgrades, fabrication, installation and hook-up, and testing and commissioning of the onshore facilities.

HEIDRUN SUBSEA EXTENSION

TechnipFMC has been awarded an iEPCI contract worth between USD$75m and USD$250m for the project. The company previously had been awarded and conducted an iFEED study. The field development will involve the installation of two new production templates with eight slots, and the drilling of five new wells; two production wells and three injection wells, plus a new umbilical to Heidrun.

BLOCK 15 REDEVELOPMENT

Oceaneering has been awarded a three-year contract to provide services in support of offshore operations in the block.

Under the agreement, the company will provide ROVs, ROV tooling, intervention workover control systems (IWOCS), satellite communication systems, subsea inspection, hydrate remediation, and engineering services.

WOLIN EAST OIL AND GAS DISCOVERY

CEPetroleum has announced an oil and gas discovery via the Wolin East 1 well drilled utilising the Noble Resolve jack-up rig. The project’s estimated to contain 200MMboe. The operator will now advance conceptual infrastructure development studies on the discovery which is located in water depths of 9.5 metres.

IRENA GAS FIELD

The operator has taken a final investment decision on the 30.5 Bcf gas field. The field is to be developed as a single platform tie-back to the existing infrastructure at Izabela field. First gas is expected in the first half of 2027.

VIETNAM GAS PROJECT – BLOCK B

A consortium of Yinson and PTSC has been awarded the contract to provide an FSO for the project. The contract includes a firm period of 14 years with a potential extension of up to 9 years. The FSO is expected to be a newbuild, double-hull, turretmoored unit to be installed in a water depth of 80m. The FSO will have a storage capacity of 350,000 barrels of condensate.

Powering the Future: Digital Transformation in Energy

Digitalisation plays an increasingly important role in helping the energy industry explore and achieve greater efficiency in operations, streamline seismic data interpretation and other data management, and develop new business models via wellsite automation or Internet of Things (IoT) integration.

By Tsvetana Paraskova

In recent years, digital transformation in the industry has helped operators and the supply chain with issue detection and asset monitoring, creating the predictive maintenance approach to ensure safe and reliable operations of well drilling, pipeline safety, turbine or refinery operations.

Just like in everyday life, digitalisation and digital devices have seen exponential use in the energy industry and will continue to be the driving force of technology and performance innovation in the sector.

Digital Transformation Market Growth

The digital transformation market in the global oil and gas industry is set to rise by 14.5 percent each year between 2025 and 2029, or by $56.4 billion in total, a report by technology research and advisory company Technavio showed earlier this year.

The surge in the use of the digital twin technology, the rise in AI-driven models for optimisation, asset utilisation, production efficiency, and risk management are driving the exponential growth in digital solutions for the oil and gas industry globally.

As digitalisation rises, the need for tech-savvy professionals to interpret the data and take decisions based on data is growing, the report says.

Data and analytics company GlobalData has identified as many as 11 technology themes out of its top 20 themes shaping the oil and gas industry in 2025.

DIGITAL TRANSFORMATION

The IEA illustrated in several case studies the capabilities of AI in energy supply, transport, and innovation. AI-powered tools help predictive monitoring in offshore wind projects. Lithium and oil extraction could also be optimised by AI-driven solutions. These could also help reduce electricity consumption with AIpower HVAC systems, and improve energy efficiency. AI satellite images also help measurement and monitoring of methane emissions in the oil and gas industry, while machine learning can enable the next level of demand response in buildings.

Specifically in the oil and gas industry, adoption of AI use cases is growing rapidly across upstream, midstream, and downstream activities, an IBM Institute for Business Value (IBM IBV) survey showed in May.

Currently, 44 percent of upstream organisations use AI in oil and gas exploration. Another 45 percent plan to do so within three years. In downstream operations, 41 percent apply AI in refining, while another 52 percent expect to do so in three years.

Leaders of 59 percent of the surveyed oil and gas companies expect AI to contribute significantly to their revenue within three years.

A total of 75 percent of industry executives say that AI investments will deliver a measurable competitive advantage within three years.

The technology themes include AI, Big Data, the Internet of Things (IoT), robotics, metaverse, blockchain, 3D printing, cloud computing, quantum computing, cybersecurity, and the future of work.

These tech themes have the capability to disrupt how things are being done in the energy industry and to help innovations and digital transformation of company operations, asset integrity, seismic surveys, and risk management.

AI and other advances in technology are also poised to transform the energy transition, enabling smart grids, demand response management, energy storage solutions, carbon capture, utilisation, and storage (CCUS), and smart homes and buildings. AI algorithms could also help forecast solar and wind power generation by analysing weather forecasts and real-time weather patterns and conditions.

Moreover, AI and AI-driven applications and tools could help optimise the energy storage of electricity generated from renewable sources. Analysing diverse factors including power supply and demand, grid conditions and connections, and prices, AI tools could determine when it is most optimal to store solar and wind energy, and when and how much to distribute.

In oil and gas, AI-led oil exploration is being led by the biggest oilfield services providers. Halliburton and SLB have filed the largest number of AI-exploration patent applications since 2021, followed by Saudi Arabia’s oil giant Aramco, according to GlobalData Patent Analytics.

AI Surge Can Transform the Energy Sector

“There has been a step change in the capabilities of artificial intelligence (AI), driven by falling computation costs, a surge in data availability and technical breakthroughs,” the International Energy Agency (IEA) said in its Energy and AI Observatory report in June.

“There is no AI without energy; at the same time, AI has the potential to transform the energy sector,” the agency noted.

More than half, 56 percent, of executives say AI will enable new technology capabilities that fundamentally transform their business model, the survey found. Moreover, 70 percent agree AI will improve their ability to navigate market disruptions, such as demand shifts, geopolitical instability, and the emergence of green hydrogen and other lower emission alternative fuels and products.

AI technologies are already delivering business outcomes, as 64 percent of executives say they are significantly revamping workflows to enhance process efficiencies and reduce manual effort, the IBM IBV survey showed.

Initiatives include automating seismic data interpretation in upstream operations, using AI for real-time data and drilling optimization, enhancing predictive maintenance in midstream pipeline networks, and optimizing refinery yields in downstream operations, IBM noted.

Oil and gas executives report a 27 percent improvement in production uptime—for example, through AI-based predictive equipment maintenance—and a 26 percent improvement in optimisation of assets utilisation.

Executives are actively working to take full advantage of AI-driven solutions.

A total of 67 percent of executives say they are actively rearchitecting how they work to capture the full potential use of AI. In addition, 58 percent believe that AI solutions can create significant value through new revenue streams—such as data-driven services, digital operations platforms, and AI-powered trading tools.

“These views pave the way for the oil and gas sector to not only optimize operations but also reimagine itself for the future,” IBM says.

Zahid Habib, Vice President, Global Industrial Sector Leader, Global Energy and Resources Industry Leader IBM Consulting, wrote in the foreword to the survey,

“For an industry defined by market volatility, leveraging AI marks a fundamental shift in how oil and gas companies can gain an edge—but it requires a balance between investments in productivity and innovation.” 

Unlocking business insights with Cetegra: A smarter way to optimise your digital resources.

| by Julie Vonnet Product Marketing Lead, Cegal

| The cost of complexity

Managing subsurface data, petrotechnical applications, and more generic business workflows has traditionally been a balancing act between technical efficiency and cost control.

Data is power — but only if you harness it effectively. This applies to all sectors of energy from oil and gas, to renewables, power and utilities. From subsurface workflows and reservoir management to smart grid optimisation and asset monitoring, energy companies generate vast amounts of data daily.

Accessing and making sense of this data is often hindered by fragmented IT infrastructures, disconnected storage solutions, and complex system architectures that make retrieval slow and inefficient. Critical insights become buried in scattered folders, outdated archives, and disorganised file structures, while rigid licensing constraints and siloed departmental setups create further roadblocks. These inefficiencies not only reduce transparency but also lead to unnecessary operational complexity and missed opportunities for optimisation.

Cegal’s Cetegra changes this by being more than just a cloud-based digital hub for hosting and deploying applications and data; it’s a specialised business intelligence engine designed for the energy sector, transforming how companies manage resources, track software consumption, and extract value from their entire digital ecosystem.

Energy companies invest heavily in specialised software, high-performance computing, and cloud infrastructure, yet many struggle to answer a fundamental question: are they using these resources efficiently?

Cloud consumption can present a major challenge, especially when data is stored in thirdparty systems, making it hard to track usage. This lack of visibility can lead to overspending on underutilised infrastructure, draining budgets and slowing down operations.

With Cetegra, that question becomes easy to answer. The platform provides critical insights into software usage, compute consumption, and collaboration patterns, all while ensuring data remains securely within the user’s own tenant. Instead of guessing how licences are utilised or where inefficiencies lie, Cetegra brings more clarity, empowering organisations to act swiftly, rationalise resources, adjust workflows, and scale operations efficiently.

| Business insights that drive smarter decisions

1. Applications license tracking and management

How many licences are actually in use? Are teams paying for software they barely touch?

by Julie Vonnet | Product Marketing Lead, Cegal

Cetegra’s built-in tracking capabilities offer complete visibility into licence consumption, ensuring companies only pay for what they need. By identifying underutilised assets, businesses can reallocate resources, negotiate smarter contracts, and eliminate wasteful spending.

2. Optimising cloud and compute resources

Energy workflows demand significant computing power and provisioning too much or too little can be costly. Cetegra provides dynamic insights into compute usage, enabling companies to scale resources based on demand. No more overprovisioning expensive high-performance computing (HPC) environments — just the right amount of power, when and where it’s needed.

3. Data access and usage insights

With Cetegra, companies gain full visibility into who accesses what data, how often, and for what purpose. This helps decision-makers track project progress, ensure data governance, and maintain transparency across teams. By understanding data consumption patterns, organisations can refine their workflows and improve operational efficiency.

| Streamlined collaboration with silos

Beyond tracking consumption, Cetegra redefines how teams interact with digital resources. Instead of working in isolation, teams can securely collaborate within a unified ecosystem, reducing delays caused by versioning conflicts, inaccessible datasets, or scattered communication.

As an illustration, BW Energy, an oil and gas operator, leverages Cetegra as a virtual workspace that enables remote teams to work simultaneously on projects, accessing data and software without disruption.

Cetegra provides the flexibility of a cloud-based solution, allowing team members to collaborate in real time, regardless of their location, all while ensuring data security and efficient resource management.

Role-based permissions ensure that the right people have access to the right tools and information, improving both security and compliance. Manual overhead is reduced, and project delivery is accelerated by integrating existing tools and applications directly within Cetegra.

This unified approach has helped BW Energy achieve a 400% growth in its operations without adding additional IT headcount, showcasing the power of Cetegra to drive business efficiency while keeping operations streamlined and scalable.

| Turning insights into competitive advantage

In a market where efficiency directly impacts profitability, Cetegra provides companies with the tools to operate smarter. By leveraging these critical business insights, businesses can maximise the value of their digital investments. The result? Lower operational costs, improved decision-making, and a digital infrastructure that works as efficiently as your team does. Get in touch today to learn how Cetegra can optimise your operations.

Contact us | sales@cegal.com

Cegal is a specialist provider of IT and Geoscience products and services to the Energy industry.

• High-performance cloud computing

• Geoscience and data management software

• Virtual data rooms

• Business intelligence and AI services

• IT consulting and Managed Services

cegal.com

From Data to Decisions: Building a Fit-for-Purpose Knowledge Infrastructure in Energy Operations

Most energy companies generate vast amounts of databut how much of it truly informs better decisions?

Across drilling, wells and operations, engineers still spend more time retrieving and interpreting data than acting on it. Despite investments in digital tools (including AI), operational knowledge remains slow to access, inconsistent, and dependent on a few individuals.

This disconnect between data and decisionmaking is a persistent bottleneck in energy operations. It’s a challenge THREE60 Digital regularly addresses in collaboration with leading operators. In this article, we’ll outline the proven principles and starting points that will help teams close this gap.

Why Data Isn’t Enough

Data alone doesn’t drive performance. To unlock value from your digital investments, organisations must transform data into usable knowledge.

• Data: Raw, fragmented inputs.

• Information: Structured facts with meaning.

• Knowledge: Context-rich insights usable across roles.

This isn’t a one-off project – it’s an ongoing shift in how teams think about and manage operational knowledge. Based on our work at THREE60 Digital, helping energy teams

navigate this transition, the most sustainable gains come from embedding knowledge practices into everyday decisions, not just deploying digital tools.

Common Pitfalls in Digital Efforts

According to BCG’s Global DSR 2020 study, up to 80% of digital initiatives in oil and gas fail to meet their objectives. Our industry is one of the lowest-performing sectors for digital transformation because we operate in high-stake, complex environments with deeply specialised workflows. Standard platforms often miss the nuances of frontline operations, where decisions depend on domain context and cross-disciplinary collaboration. Projects also run alongside legacy systems and fragmented information sources, overburdening technical teams.

A better approach is to let real-world workflows lead the way. Ensure solutions are built around actual practices, with digital and operational teams collaborating from the outset.

Three Practical Foundations for Better Knowledge Systems

Based on lessons from real-world operations, a knowledge-first approach rests on three pillars:

1. Start with Business-Driven Use Cases

Focus on specific, high-impact use cases (e.g. Improving NPT tracking, automating well handovers, or identifying recurring equipment failures). Define data needs based on business priorities – don’t collect “all data.”

2. Bridge Domain and Digital Early

Involve operational experts in design, not just review. THREE60 Digital’s projects show that early co-creation builds trust and drives adoption.

3. Build for Modularity and Learning

Avoid locked-in platforms. Use flexible, composable components that evolve with needs and support continuous iteration.

What Progress Looks Like

Teams adopting a knowledge-first approach often report:

• Faster access to relevant information

• Reduced reliance on specific individuals to interpret data

• Improved collaboration across roles

• Easier capture and reuse of lessons learned

Achieving perfection isn’t the goal. It’s about building momentum and removing friction in everyday work.

A Shared Opportunity

In an industry that thrives on precision and performance, knowledge is as important as engineering. As operations grow more complex and cycles shorten, organisations that prioritise fit-for-purpose knowledge systems will adapt, improve, and lead.

The first step isn’t a new tool, it’s a shared conversation. At THREE60 Digital, we’re always open to exchanging ideas and helping teams reflect on how knowledge can better serve their operations. 

Smart Hose Management Starts with THM

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

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

Structured to Perform: Software Engineering at the heart of digital subsea operations

By Michael Topp, Elementz Chief Software Engineering Officer

As the energy sector accelerates toward a digital-first future, the expectations placed on software engineering teams have never been higher.

At Elementz, we’re not just building digital products, we’re building solutions that enable critical infrastructure to operate safer, smarter, and more sustainably beneath the waves. And to do that well, we’ve had to think differently about how we engineer.

The shift we’re seeing across oil and gas, offshore wind, and broader subsea infrastructure isn’t just about automation or dashboards. It’s about integration, technological, organisational, and ecosystemlevel integration.

This is the backbone of what we call the Blue Digital Ecosystem: a growing convergence of systems, tools, and data sources that drive smarter inspection, integrity, and risk management strategies across marine energy assets.

But making this vision a reality requires more than product ambition. It demands an engineering structure built to deliver at scale; predictably, securely, and collaboratively. That’s the journey we’re on at Elementz.

Reframing Engineering for Ecosystem Impact

When we first launched Elementz, our core focus was building reliable, industry-grade inspection and integrity software. Today, our mission has evolved: we’re now rearchitecting for scalability and adaptability, guided by our new product strategy - Expand, Integrate, Co-Create.

This framing doesn’t just apply to the product. It defines how we structure our engineering team:

• Expand means extending core product capabilities through modular design and proprietary enhancements. Our engineering teams are now organised around strategic product areas like visualisation, field data workflows, and AI-supported tools, each aligned with end-user value.

• Integrate reflects our focus on seamless API connectivity with enterprise systems and leading 3rd party applications such as Digital Twins. We’ve built dedicated squads to support enterprise integration and ensure Elementz fits naturally into clients’ digital ecosystems.

• Co-Create points to a growing network of partners and clients who shape our roadmap; from user forums to third-party plug-ins. Engineering teams participate directly in these collaborations, embedding client feedback into every sprint.

Engineering Infrastructure That Scales with Purpose

To support this evolution, we’ve made major investments in infrastructure. This includes secure identity systems, audit-ready compliance frameworks and automated testing pipelines to reduce QA overhead while improving reliability.

We’ve introduced structured observability so both our engineers and customer teams can see what’s happening under the hood. By shifting away from reactive support to proactive monitoring, we empower our engineers to spend more time innovating and less time firefighting.

We’ve also aligned our release cadence to support consistent delivery: fewer hotfixes, more predictability, and a deliberate focus on customer-informed improvements.

Building a Team That Thrives

Performance isn’t just about architecture, it’s about people. At Elementz, we’ve worked hard to build a culture where engineers are empowered, engaged, and aligned. Our learning and development framework encourages multiskilling and ownership. Engineers can move between areas, from backend service orchestration to front-end design enhancements, guided by a career ladder that’s transparent and achievable.

Through our collaboration with MSc and undergraduate students, and the expansion of our office space, we’re making space, literally and figuratively, for growth. And beyond the code, a dedicated social committee ensures that our team culture remains strong, connected, and sustainable.

Customer Proximity as an Engineering Principle

One of the most important cultural shifts we’ve made is bringing engineers closer to our customers. Embedded tools give us behavioural data, but it’s the direct engagement, through customer advisory boards, forums, and strategic partners, that makes the difference.

We’ve operationalised these insights across the product: from optimising 2D visualisation and media reporting features to exploring advanced agents for automated anomaly recognition. In this way, Software Engineering becomes a vehicle not just for delivery, but for co-creation.

A Platform, and a Team, Built for the Blue Economy

The challenges of subsea asset integrity aren’t limited to oil and gas. From offshore renewables to subsea communications and defence infrastructure, we see an expanding opportunity for Elementz to support the wider Blue Economy.

That’s why we’ve built our engineering organisation to be resilient, modular, and user-focused, ready not only to meet today’s demands but to shape tomorrow’s capabilities.

Our goal is simple: to be the engineering team behind the solution that defines the digital future of subsea operations. And that means continuing to expand what we offer, integrate with the world around us, and co-create the solutions that matter most.

Envizion: Transforming Asset Operations with AI and Digital Twins

Envizion is a technology driven company based in Aberdeen, Scotland, specialising in AI powered digital twin solutions. Working with major operators & EPC’s to help operate more efficiently, sustainably, and strategically.

The technology is multi-industry and multi-disciplinary, supporting engineering, construction, maintenance, inspection, asset integrity, and operations.

At the heart of Envizion’s offering is AVA, an integrated digital platform that delivers fully immersive 3D environments, bringing together point clouds, layout plans, intelligent

P&IDs, and more - in a single interactive space. It enables users to navigate facilities virtually, access documents instantly, plan and schedule work efficiently, and optimise resources. Using advanced machine learning and AI, AVA also provides predictive intelligence to detect corrosion, identify patterns, and deliver actionable insights for proactive maintenance and improved decision making.

The platform can integrate seamlessly with existing client systems, giving organisations a single, reliable source of truth for all asset and operational data.

Envizion also offers specialist site services, such as high precision data capture to create accurate, up to date digital representations of assets, even in complex brownfield environments. This ensures Envizion’s digital twins and AI models are always reliable, enabling faster decision making and reducing costly site visits.

In addition to technology solutions and data capture services, Envizion offers consultancy services that help clients develop and implement digital strategies, integrate systems, and optimize operational workflows. The consultancy approach combines technical expertise with deep industry knowledge, enabling Envizion to deliver tailored recommendations that align with each client’s goals.

Through the combination of advanced technology, precise data capture, and strategic consultancy, Envizion helps organizations unlock predictive maintenance, reduce costs, and improve operational efficiency, achieving significant ROI while supporting sustainability across the asset lifecycle. 

Come visit Envizion at the OGV Pavilion –stand 2L40

is a global leader in wellhead engineering, headquartered in Aberdeen With 40 years of industry expertise and over 500 wells drilled, we deliver high performance, adjustable

For more than 50 years, Petrasco has been the trusted name for specialised logistics solutions serving the global energy industry.

With its headquarters in Dyce, Aberdeen complemented by regional hubs in Dubai and Houston, Petrasco’s strength lies in its local, on-the-spot decision making. Its team works tirelessly to keep vital components flowing to maintain production and operations on behalf of clients around the world.

The past five decades have seen Petrasco evolve from a solely Aberdeen-focused company to one with international reach, which makes it ideally placed to provide expert knowledge on emerging markets and trends through its network of strategic partners.

Petrasco remains proud of its roots and has supported several other north-east companies establish a foothold in overseas territories. By providing access to services and equipment, it empowers them to mobilise quickly and cost-effectively without the need for expensive, long-term commitments..

Built in the North Sea, delivering expert logistics solutions to the world

Building on the success and growth of the business over the past 50 years, Petrasco continues to expand its key services with an increasing number of renewable energy workscopes either completed or currently in progress – highlighting the company’s commitment to the energy transition.

Recent high-level projects with key, longstanding clients have demonstrated the full range of capabilities possessed by Petrasco: everything from air, road and sea freight to customs compliance and in-country support.

This year marks the first time Petrasco has exhibited at Offshore Europe as a standalone business, having previously shared a stand alongside other Denholm Energy Services group companies.

Meet the Petrasco team at the OGV Pavillion (Hall 2) where they will be on hand to discuss any service requirements you may have throughout the week, while the company is also sponsoring the OGV Group drinks reception and attending both golf networking days. 

Customs Compliance & Consultancy

Warehousing & Distribution

PD&MS: Your Trusted Lifecycle Partner.

The UKCS oil and gas industry has a challenging backdrop, as a mature basin with declining reserves and falling production levels, workforce issues, higher taxation rates along with the need to transition to a lower carbon future.

The Industry Standard Software for Topsides Process Performance Analysis Achieves New Milestone!

MySep Pte Ltd, with its headquarters in Singapore, is a global leader in separation system modelling and optimisation.

Its software is adopted by the world’s leading energy operators—including ExxonMobil, Chevron, Total Energies, BP, Oxy, Harbour Energy and many more—who rely on MySep products to enhance operational performance, design and retro fit. In fact, many of these operators mandate the use of MySep software by engineering contractors, consultants and equipment vendors on both greenfield developments and brownfield upgrades, ensuring consistent, high-quality separation analysis across project lifecycles.

At Offshore Europe 2025, MySep unveils two key advances in separation technology with the release of v6.1 software. MySep Engine v6.1 introduces rigorous liquid-liquid separation analysis to activated process digital twins on leading platforms such as Aspen HYSYS® and UniSim® Design—an industry first for process simulation. Engineactivated digital twins are being connected to live facility data, enabling real-time predictive monitoring that helps engineers identify concerning performance trends, anticipate issues, and make proactive adjustments to reduce downtime and optimise throughput.

MySep Studio v6.1 adds comprehensive oil-in-water and water-in-oil prediction capabilities, independent of inlet water-cut or operating conditions—supporting more accurate diagnostics and enabling operational adjustments or retrofit evaluations.

In topsides processing, separation performance is the linchpin of sustainable and profitable production. Poor separation can lead to liquid carry-over with gas, compressor damage, and costly shutdowns. Just as critically, separation constraints can limit production throughput, as operations struggle to meet oil-in-water discharge limits, or export gas dew-point specifications. MySep’s software products equip process engineers to tackle these challenges headon—supporting operational diagnostics, design assurance and vendorindependent retro-fit evaluations.

Stop by Booth 2L40, in the OGV Pavilion, where the MySep team will be happy to discuss any separation modelling or evaluation issues, and demonstrate our products and services.

Reach out to: tom.ralston@mysep.com or eric.vos@mysep.com to pre-arrange a meeting

EXCEED Continues to Lead the UK’s Energy Transformation

Wells expertise remains critical to the transition to a lower carbon future, through maintenance of the integrity of existing wells, the recycle and repurpose of existing assets and the permanent abandonment of former oil and gas wells.

Leading well and reservoir management specialist, Exceed’s impact on the energy industry is based on project management expertise, outstanding technical and commercial capabilities, and the ability to seamlessly become a part of its clients’ teams.

UK’s Leading Independent Well Operator

Earlier this year, Exceed announced that it had secured what it terms as “one of the most significant contract wins” in its 20-year history.

Appointed as Well Operator for the 192 wells which will comprise Viaro Group’s One Gas West assets following completion of the acquisition from Shell and ExxonMobil, Exceed will manage all aspects of late life well operations, starting with the decommissioning of the 26 wells associated with the SNS Leman Foxtrot and Golf platforms, which commences later this year.

Subsequent activity within the five-year, £multi-million contract’s term will include well intervention and further decommissioning operations, as well as the development of new gas production wells, widely regarded as an energy transition fuel.

John Anderson, Exceed’s Commercial Director – Wells commented: “Our well and reservoir management capabilities have gained an outstanding reputation for the ability to balance

decarbonisation with energy security and affordability, as we continue to champion a sustainable UK energy transition.

“Understandably, this contract has been keenly contested across the North Sea industry, and we are delighted that our capacity and competency have been recognised by Viaro as providing optimum levels of expertise and support for its major acquisition.”

Since gaining Well Operator status in 2022, Exceed has established itself as the North Sea’s leading independent Well Operator, and will now be managing over 200 wells throughout the region, on a scale commensurate with major North Sea operators.

Pushing Boundaries to Ensure a Lower Carbon, Energy Secure Future for the UK

And in late 2024, Exceed announced its role in the initial stages of a world leading clean energy project, which could result in the creation of more than 30 jobs at the Aberdeen-headquartered company.

With the knowledge and experience to develop hydrogen-ready wells, the company was selected by Centrica Energy Storage (CES+) as a Tier One partner, alongside Wood, for the front end works specific to the redevelopment of the UKCS Rough field.

As RougH2, the UK’s largest proven gas storage facility may provide hydrogen ready facilities that could allow storage of up to 260 billion cubic feet of gas. This would be pivotal in ensuring the security of the UK’s energy supply and the facility could ultimately create approximately 4,000 jobs, whilst lowering energy costs.

Exceed’s workscope will include the provision of integrated multi-discipline subsurface engineering, field redevelopment planning and delivery, and well project management of the design.

The FEED contract award to Exceed follows the successful completion of a Rough Redevelopment engineering pre-FEED phase, and eight-month integrated CCS pre-FEED transition engineering study in support of the Morecambe Net Zero (MNZ) cluster, owned by Centrica Energy Storage and Spirit Energy.

Ian Mills, Exceed Managing Director, commented: “Without question, RougH2 is critical to the success of UK’s energy transition. This contract makes clear the necessity for, and transferability of, well and reservoir management capabilities throughout that journey, and we take pride in our involvement in this landmark project.

“Exceed is increasingly recognised for our commitment to a highly collaborative approach. We are delighted to be working closely with both Centrica and Wood to deliver a project which is genuinely pushing boundaries to ensure a lower carbon, energy secure future for the UK.”

Defining Decom Standards

Exceed continues to answer some of the biggest decom challenges through the design and build of innovative solutions – including a world first response to the complex issues around the integrity of ageing subsea wellheads.

Its team doesn’t just solve problems; it anticipates them to ensure every project is executed to the highest safety and operational standards.

A unified decommissioning unit comprises a team of highly skilled and experienced professionals from multiple disciplines –subsurface, decommissioning, well services, subsea, contracts and well engineering. This integrated approach allows Exceed to address even the most complex surface and subsea challenges with precision, efficiency, and innovation.

Exceed thrives on tackling the unique challenges inherent in offshore decommissioning. With a “can-do” attitude and a commitment to thinking outside the box, its team collaborates closely with clients and the supply chain partners to design and implement complex, bespoke subsea solutions. Whether addressing intricate well abandonment scenarios or overcoming subsea engineering hurdles, Exceed continually delivers results that inspire confidence.

In addition, a dedicated vessel-based decommissioning team provides a carbon neutral, fully-compliant subsea wellhead removal service. Removing postdecommissioning liability, clients also benefit from cost efficiencies via a campaign approach.

Exceed’s collaborative approach to decommissioning has been typified by the official launch of a collaborative agreement with DeepOcean to supply vessel-based well plugging and abandonment services to the global decommissioning market.

Characterised by their “one team” approach, the companies’ single contract solution offers a turnkey service including equipment, planning, execution and close-out, leaving a full audit trail to ensure optimum repurpose and reuse of retrieved assets.

The partnership commenced with an agile multi-well vessel-based P&A campaign on behalf of Serica Energy in 2024, which resulted in significant time and cost-savings, and reduced CO2  impact, when compared with rig-based P&A activity. 

Safer, Smarter, Solutions

GQS are a worldwide provider of inspection, auditing, and quality assurance services to the renewable energy industry and all other major industries, including Offshore Wind, Hydrogen, and Oil and Gas, supporting your needs throughout every stage of your project’s lifecycle to make sure your projects safely meet the right requirements.

With offices strategically located around the globe to accommodate the needs of our clients, including a local office in Aberdeen (Scotland) as well as a network of global offices in Norway, Senegal, Singapore, Malaysia, Vietnam, India, Taiwan, China, Australia and most recently Canada, USA, and Italy.

This has allowed GQS to provide support to several major renewable energy projects around the world in the past year. Some of our recent projects include:

• Managing worldwide inspection for the Hydrogen Refueller Project, operated by Woodside Energy Technologies in Western Australia.

• Providing extensive onshore and offshore inspection services for the Hai Long offshore wind farm in Taiwan.

• Delivering supervision and technical support for the construction of the Horizon Offshore Management Cable Laying Vessel.

“GQS have been providing services to the renewable energy sector for several years and we continue to build our expertise to meet the needs of clients operating in the existing and emerging renewable energy sectors. We are successfully delivering on major, multi-millionpound projects around the world, helping our clients meet their objectives efficiently, safely, on-time and within budget.”

GQS have a comprehensive range of experience providing QA/QC Services worldwide to both Operators and Tier One Contractors. Our high level of service, fast decision making, and client-first systems customisation have been essential to building long-lasting relationships for clients.

All project inspection operations are controlled through our best-inclass bespoke software system, GQS Connect. A software that adds value to our client’s inspection processes, cost allocation, and tracking, which can be accessed at all times through a web-based browser.

GQS join OGV Energy at Offshore Europe in Aberdeen from 2nd – 5th September 2025 in P&J Live (Hall 2) as part of the OGV Energy Pavilion.

We look forward to discussing how our quality services can assist your project.

Scan the QR code or visit our website to find out more.

Quality today, for a safer tomorrow.

Always GQS.

Kranji Solutions –Separation Expertise Driving Offshore Production Performance

Kranji Solutions Pte Ltd, is a specialist engineering consultancy delivering high-impact solutions worldwide for separation system performance in offshore oil and gas production.

With nearly two decades of experience, Kranji is a trusted partner to leading international operators and licensors, providing vendor-independent expertise across greenfield developments and brownfield upgrades.

Separation systems are critical to safe, efficient and sustainable offshore operations. Underperformance can lead to liquid carryover with potential for degraded compressor performance and risk of machine failure. It can lead to excessive consumption of costly solvents and give rise to production short-fall where for example, dew-point specifications are carry-over constrained. Kranji helps its global customers overcome these challenges through advanced diagnostics, root cause investigations, and retrofit strategies tailored to complex offshore and onshore processes.

Kranji’s approach combines expert multiphase Computational Fluid Dynamics (CFD) and MySep process evaluations, combined with deep industry phase separation expertise. Its track record includes successful troubleshooting and debottlenecking projects on FPSOs, fixed platforms and onshore production installations, where separation constraints are found to be limiting throughput or compromising export specifications. Kranji provides analysis of performance issues and viable retro-fit solutions that are equipment vendor agnostic. Kranji regularly provide predicted performance for the remediated system and, at customer request, will operate as the project EPC procuring required equipment from reliable market suppliers.

The company is also the original creator of MySep products which are recognised as the industry-standard separation modelling and design software, now developed and licensed globally by Kranji’s sister company, MySep Pte Ltd. Kranji operates a multiphase R&D and test facility in the Netherlands and is often contracted by leading Energy operators and Licensors to assist in development or performance verification of proprietary separation equipment. 

Stop by Booth 2L40, in the OGV Pavilion, where the Kranji/MySep team will be happy to discuss any separation performance issues.

Please reach out to tom.ralston@kranjisolutions.com or eric.vos@kranjisolutions.com to pre-arrange a meeting.

View From Management: Phil Scott Adapting to a Tighter Market Through Collaboration and Smarter Operations

The energy sector is facing one of its most challenging periods in recent history. Global market volatility, combined with stricter capital expenditure (CAPEX) and operational expenditure (OPEX) controls, is forcing businesses across the supply chain to rethink how they operate. The days of simply “doing more” are behind us—now, the focus must be on doing better

In this climate, success will belong to those who can reduce inefficiencies, extend asset life, and lower maintenance costs without compromising on safety or performance. It’s about working smarter, not harder. That means optimising every aspect of asset management—from inspection and certification through to storage, utilisation, and redeployment.

At Intervention Rentals, we believe the key lies in collaboration across the supply chain. For too long, service providers and operators have worked in silos, with duplicated effort, fragmented data, and competing priorities. By breaking down these barriers and sharing information more effectively, we can remove waste, reduce downtime, and collectively achieve better results.

Technology plays a critical role in enabling this shift. Digital tools now allow for real-time monitoring, predictive maintenance, and fully traceable records. These capabilities mean we can identify potential failures before they occur, schedule maintenance with precision, and provide transparent reporting that supports compliance while reducing manual administration. By adopting these systems, we can move away from costly reactive interventions and towards proactive, datadriven decision-making.

However, technology alone is not enough. It must be paired with a mindset that prioritises value over volume. This requires reviewing traditional practices and asking tough questions: Do we need to own e very asset we use? Can we extend inspection cycles without compromising safety?

Are there opportunities to share or pool resources with partners? Every decision should be measured not just on immediate cost, but on long-term return on investment and impact on operational continuity.

The reality is that high CAPEX projects are harder to justify in today’s environment. Operators are looking for ways to defer largescale spending while still meeting production and safety targets. This is where the supply chain must step up—offering innovative commercial models, flexible access to equipment, and services that genuinely reduce total cost of ownership.

For Intervention Rentals, this means delivering more than just equipment. It’s about providing complete asset management solutions that ensure our customers always have the right, certified, and fully compliant equipment available when they need itwithout the burden of unnecessary ownership or maintenance costs. By integrating our services into our clients’ operational planning, we help them free up space, reduce staffing requirements for equipment management, and lower QHSE risks on site.

In a market where margins are under pressure, standing still is not an option. The companies that will thrive are those that embrace collaboration, leverage technology intelligently, and focus relentlessly on costefficiency without compromising standards. By aligning our capabilities with these priorities, we are not only responding to today’s challenges—we are building a stronger, more resilient future for our industry. 

Aurora Energy Services make key appointment ahead of recruitment boost of more than 300 staff

Aurora Energy Services (Aurora) have created a new strategic role in anticipation of a huge expansion of its onshore and offshore workforce.

Leigh-Ann Robb has been appointed Resourcing Manager to support and direct the company’s UK and international resource needs across multiple business lines.

Recent project wins and a strong pipeline of future workscopes in onshore and offshore wind, engineering, oil and gas, and industrial infrastructure sectors, means Aurora is looking to add potentially 350 to its headcount over the next 12-18 months.

Leigh-Ann Robb has more than 18 years’ experience supporting offshore construction and operational teams in the oil and gas sector alongside proven expertise in logistics coordination, recruitment, mobilisation planning, and client liaison.

Compliance and engineering appointments strengthen STATS Group offering

STATS Group (STATS) has announced two key appointments which bolster their legal and compliance and engineering capabilities.

The pipeline technology company – a leading provider of pressurised pipeline isolation, hot tapping and plugging services to the global energy industry – has appointed Adam Morrice as Legal and Compliance Director based in the company’s Kintore headquarters in Aberdeenshire, Scotland.

Previously Adam held senior positions with Expro as Legal & Contracts Manager and most recently he was Head of Legal at Trojan Energy. As a member of the Executive Committee, he leads the renewal of STATS’ legal, contract, risk and compliance functions, working closely with global and regional leadership teams on contractual oversight, regulatory compliance, policy development and strategy.

Vince Kolbuck joins the company as Global Engineering Manager based in Houston, USA. Vince will work closely with engineering teams across Canada, the USA, the Middle East, Asia Pacific and UK, ensuring strategic alignment of regional and global engineering priorities with clients’ needs. 

Before joining Aurora she was Operations Manager at Katoni Engineering and Nexos Solutions in Aberdeen, and prior to that held a number of senior operational roles at Petrofac Facilities Management.

Aurora Energy Services Chief Executive Officer, Doug Duguid, said: “In response to wide range of growth opportunities within the UK and internationally, we have established a new role of Resourcing Manager to enhance our existing capability, and to allow us to deliver a significantly larger workforce for both on and offshore projects.

“Leigh-Ann is adept at working in highpressure, fast-paced environments while delivering operational excellence.”

Former CFO Alan Jordan Returns to Cargostore Worldwide as Chairman

Experienced financial leader to guide UKbased container specialist through next phase of growth in offshore energy and industrial sectors

Cargostore Worldwide, a leading UK-based provider of offshore and ISO shipping containers to global wind farm, oil and gas, mining, and stability projects, today announced the appointment of Alan Jordan as Chairman of the Board effective August 2025.

Jordan previously served as Cargostore’s Chief Financial Officer from April 2017 to April 2023 during which time he played a pivotal role in the company’s strategic development including leading the financial aspects of a £24 million secondary management buyout backed by Connection Capital. Under his financial stewardship Cargostore more than doubled profits developing strong recurring revenues from long-standing blue-chip customer relationships.

His return to the company in the elevated position of Chairman reflects both his deep understanding of Cargostore’s business and the board’s confidence in his proven strategic and financial leadership capabilities. 

MacArtney appoints General Manager to lead Sweden office amid growing market demand

MacArtney Underwater Technology has appointed Håkan Sundin as the General Manager of its Sweden operation. This appointment reinforces the company’s dedication to local engagement and collaboration with Swedish customers.

The move supports MacArtney’s ambition to establish a fully-fledged presence in Sweden and further its role as the go-to partner in underwater technology.

Since opening the office in Mölnlycke near Gothenburg in 2022, MacArtney has seen growing recognition from the Swedish market. The local presence has enabled closer partnerships across the marine and offshore, ocean science, and naval sectors, as well as with academic and scientific institutions.

“Our presence in Sweden is translating into stronger partnerships and more responsive support. Håkan’s appointment underscores our long-term commitment to the region and our belief in collaboration as the foundation for reliable, high-performance underwater solutions,” says Rasmus Frøkjær Bonde, CCO at MacArtney. 

3t Appoints New VP to Lead Saudi Training Centre, Driving Vision 2030 Workforce Goals

• GTSC, part of 3t, has appointed Askar Salem Alyami as Vice President of its Saudi Arabian training operations to strengthen its growth and support local talent development in line with Saudi Vision 2030.

• Askar will lead the GTSC training centre, enhancing its role in 3t’s global network to equip Saudi professionals with skills for the evolving energy landscape.

• Askar Salem Alyami, Vice President of 3t’s GTSC Saudi Arabian training operations, said:

• “I’m honoured to join 3t at such a pivotal time. I look forward to driving strategic partnerships and delivering world-class training that supports Vision 2030. Together, we’ll grow GTSC’s impact, strengthen workforce development, and accelerate 3t’s success across Saudi Arabia and beyond.”

Dammam, Saudi Arabia – 30.07.2025 –GTSC, part of 3t, the leading global provider of workforce training and competency for safety-critical industries, has announced the appointment of Askar Salem Alyami as Vice President of its Saudi Arabian training centre operations.

This strategic appointment marks a significant step in 3t’s continued commitment to advancing its growth story in the Kingdom and supporting the development of local talent to meet future energy challenges.

In his new role, Askar will oversee the company’s Dammam training centre operations, positioning it as an integral part of 3t’s global training and development network. The centre plays a vital role in equipping the next generation of Saudi professionals with

the skills, knowledge, and expertise needed to drive innovation and sustainability in the energy sector, in full alignment with the goals of Saudi Vision 2030.

Askar Salem Alyami, newly appointed Vice President of 3t’s GTSC Saudi Arabian training operations, said: “I am honoured to join 3t at this pivotal time and look forward to driving strategic partnerships and delivering worldclass training that supports the Kingdom’s Vision 2030 transformation goals

“Together with our talented team, I aim to bring my experience to expand GTSC’s presence in key sectors, improve workforce development and industrial excellence across Saudi Arabia, while accelerating 3t’s growth story in the region and take our success to new heights, both locally and globally.” 

This week’s leading oil and gas appointments

Impact Oil & Gas appointed Bjorn Thore Ribesen as ichief operating officer.

David Rosner appointed chairman of the US Federal Energy Regulatory Commission (FERC), following departure of Mark Christie

Blue Water chief operating officer for energy, ports and projects, Thomas Bek, to take over as chief executive from Soren Norgaard Thomsen, who is leaving the company

Subsea technology player Nortek appointed Bjorn Ladegaard as executive vice president.

Angus Energy appointed Alex Craig and Richard Glass as non-executive directors.

Mohd Khairi Baharom starting a new position as head of operations at EPOMS, the Malaysian operations & maintenance (O&M) solutions provider.

BHP’s Tim Day named as new president of the Chamber of Minerals and Energy of Western Australia, while the resources advocacy group continues search for new chief executive.

Beatrice Bienvenu has been appointed to lead Chevron’s exploration activities in Namibia and West Africa as country manager.

Pui Ling Tang starting a new position as senior human resources business partner at Aker Engineering Malaysia.

David Millenaar starting a new position as project manager BPS at SBM Offshore in Monaco.

Pipeline technology company STATS Group has Adam Morrice as legal and compliance director, while Vince Kolbuck joins the company as global engineering manager. 

Jobs Board Latest Vacancies

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.

For more information on these, plus many more vacancies visit ogv.energy

White Cross Offshore Windfarm receives full planning consent

Major boost for floating offshore wind in the Celtic Sea as White Cross receives full consent

Leading offshore wind developers Flotation Energy and Cobra have announced that their pioneering Celtic Sea floating offshore wind project, White Cross, has been granted full onshore and offshore planning approval.

The White Cross Offshore Windfarm project, applied to North Devon Council and the Marine Management Organisation (MMO) in 2023 to construct and operate a 100MW floating offshore windfarm and for works to connect the windfarm to the grid.

The proposed windfarm, located 52km off the Devon coast, will consist of six to eight state-of-the-art floating wind turbines and, when operational, will generate enough clean electricity to power around 135,000 households.

The offshore application was submitted to the MMO in March 2023, and the onshore planning application was submitted to North

Devon Council in September 2023. The applications were the subject of three rounds of public consultation.

Following the approval at North Devon Council’s Planning Committee on Wednesday 7 May, the council has now granted consent for the onshore elements of the project.

Meanwhile the Marine Management Organisation has issued a Marine Licence under the Marine and Coastal Access Act 2009 to enable the offshore elements of the project in accordance with the South West Marine Plan.

“This is an important moment for the White Cross Offshore Windfarm, and for floating offshore wind in the Celtic Sea. We are grateful to the North Devon Council and the Marine Management Organisation, and to everyone who has engaged with the project. In response to feedback, we have adapted our plans to minimise environmental and social impacts.

“The UK is already a leader in floating offshore wind technology, but until now this has only been via projects in Scottish waters. This decision gives us a valuable opportunity to harness this pioneering technology to help deliver the energy transition in the south west of England. By doing so, we will seek to spark the development of a specialised local supply chain, creating jobs whilst providing 135,000 homes with renewable energy.”

White Cross Senior Project Manager | Sam Park

White Cross Offshore Windfarm’s offshore export cable(s) will make landfall at Saunton Sands beach, before connecting to the onshore export cable(s). The onshore export cable(s) will be completely buried underground for their entire length and will travel approximately 8km to a new White Cross onshore substation which will accommodate the connection to the existing East Yelland substation. The cable(s) will pass beneath Braunton Burrows and the Taw Estuary via trenchless technology, designed to avoid any surface disruption within the Braunton Burrows Special Area of Conservation (SAC) dune system and the TawTorridge Estuary SSSI.

White Cross is a stepping stone project that is pivotal to the Crown Estate’s ambitions to scale-up and commercialise floating energy technologies in the Celtic Sea.

The project supports the UK Government’s target for offshore wind, alongside wider decarbonisation and energy security targets. White Cross will also play a key role in supporting the growth of a regional supply chain, whilst also creating new jobs and skills for local communities. 

Green light for Berwick Bank paves way for world’s largest offshore wind farm

 Scottish Government grants consent order for SSE’s Berwick Bank offshore wind farm, after a decade of meticulous development work

 Berwick Bank has the potential to inject c.£8 billion of value into the UK economy and create over 9,000 UK jobs

 At full capacity, Berwick Bank could generate enough electricity to power more than six million homes annually

SSE welcomes the Scottish Government’s decision to grant consent for the pivotal 4.1GW Berwick Bank offshore wind farm, located around 38km east of the Scottish Borders coastline, boosting Scotland’s net zero ambitions and the UK’s clean power mission.

Today’s Section 36 consent determination by Scottish ministers approves the project’s main offshore wind farm array in the outer Firth of Forth off the East Lothian coast.

The decision represents the last major consent necessary for the project to proceed and is the culmination of more than a decade of meticulous development work by SSE Renewables on the project’s design.

Delivery of the project will now be subject to SSE securing a contract for new low-carbon offshore wind power under the UK’s Contracts for Difference (CfD) scheme, as well as reaching a final investment decision.

Berwick Bank offshore wind farm is vital to the UK’s 2030 clean power mission and to the energy security goals of the Scottish and UK governments.

If fully delivered, Berwick Bank would become the world’s largest offshore wind farm, capable of generating enough clean energy to power more than six million homes annually.

Berwick Bank has the potential to create 9,300 direct, indirect and induced jobs in the UK at peak construction – with around 4,650 of these jobs in Scotland. Over the project’s expected lifetime, it is estimated Berwick Bank could inject £8.3 billion of value into the UK economy.

Securing consent for the main offshore wind farm array is a vital step towards the UK Government’s mission, as set out in the Clean Power 2030 Action Plan, to increase installed offshore wind capacity to up to 50GW as part of a mass deployment of offshore wind over the next five years.

The project could increase Scotland’s current operational renewable electricity capacity by almost 25%, boosting the country’s efforts to achieve net zero carbon emissions by 2045.

Stephen Wheeler, Managing Director, SSE Renewables said:

“The Scottish Government’s decision to grant a consent order for Berwick Bank Offshore Wind Farm is hugely welcome. At over 4GW of potential capacity, Berwick Bank can play a pivotal role in meeting the mission of Clean Power 2030 for the UK and achieving Scotland’s decarbonisation and climate action goals.

“As the UK’s clean energy champion, SSE now looks forward to the UK Government delivering the most ambitious CfD scheme yet through the upcoming AR7 auction round.

“Berwick Bank has the potential to rapidly scale-up Scotland’s operational renewable energy capacity and can accelerate the delivery of homegrown, affordable and secure clean energy to UK consumers from Scottish offshore wind, helping meet the UK’s clean power ambition by 2030.” 

Berwick Bank Site Boundary and Grid Routes

Managing cyber risk - new laws and government guidance to help businesses in the UK

The recent high profile cyber attacks on Marks and Spencer and the Co-op have highlighted the devastating impact a cyber attack can have on an organisation and the importance of managing cyber risk in your supply chain

Other recent high profile cyber attacks have affected the Ministry of Defence, NHS bodies and local authorities. In 2023, a number of well known charities were the subject of a cyber attack on a third party IT platform used to store information on supporters.

Supply chain cyber risk doesn't just apply to an organisation's IT service providers - a cyber attack on a business-critical supplier can also be highly damaging. For example, if a manufacturing business suffers a cyber attack on its logistics provider or the supplier of raw materials, then it may be unable to get products to market.

A similar situation in the energy industry would have almost immeasurable consequences and the risks are increasing. A report published by Sophos in July 2024, which surveyed 275 cybersecurity and IT leaders from the energy, oil/gas, and utilities sector across 14 countries, found 67% of respondents said their organisation had suffered a ransomware attack in the previous 12 months.

In the case of Marks and Spencer, it confirmed that hackers had gained access to its systems via a third party service provider, providing a timely reminder that organisations need to take a holistic view to cyber risk and focus on governance and supply chain risk.

To help organisations improve their cyber resilience and manage cyber security risk, the UK Government is proposing to introduce new legislation. This legislation will accompany a number of voluntary codes of practice that have been developed by the Government in conjunction with the National Cyber Security Centre.

Cyber Security and Resilience Bill

The Cyber Security and Resilience Bill is designed to modernise and expand the country’s cyber security framework. For the energy sector—already classified as part of the UK’s Critical National Infrastructure (CNI)—it signals a shift in regulatory expectations and operational responsibilities.

Since 2018, the UK’s cyber security regime has been governed by the Network and Information Systems (NIS) Regulations, which implemented an EU Directive targeting operators of essential services, including energy, transport, water, and health. However, the scope of these regulations has proven limited in the face of evolving cyber threats and increasingly complex supply chains.

Key provisions of the Bill

The Cyber Security and Resilience Bill introduces several new measures that will directly impact energy operators:

• Sector expansion: cyber obligations will extend to new sectors and entities, reflecting the interconnected nature of modern infrastructure.

• Managed Service Providers (MSPs): MSPs delivering IT services to energy companies will face similar obligations to cloud providers, with the intention of improving resilience across outsourced IT services.

• Supply chain duties: operators of essential services must ensure cyber resilience throughout their supply chains, with potential flow-down obligations to subcontractors and vendors.

• Critical supplier designation: The Government will gain powers to designate certain suppliers as “critical,” subjecting them to enhanced oversight and compliance requirements.

• Incident reporting enhancements including:

- 24 hour obligation for initial notification

- new obligations in relation to ransomware attacks

- transparency obligations requiring providers of digital services and data centres to alert customers who may be affected by incidents

• Regulatory flexibility: The Bill allows updates to the cyber framework via secondary legislation, enabling swift responses to emerging threats.

• Data Centres as CNI: Following their designation as critical infrastructure in 2024, data centres may also be subject to new cyber resilience obligations.

Energy companies must prepare for deeper scrutiny of their digital ecosystems, particularly where third-party IT services and operational technology intersect. The Bill’s emphasis on supply chain resilience and rapid incident reporting will require updated governance, contractual frameworks, and technical capabilities.

Supporting Codes of Practice

To complement the new legislation, the Government has introduced a suite of voluntary Codes of Practice aimed at improving cyber governance and technical resilience:

• Cyber Governance Code of Practice: Published in April 2025, this code offers boards and senior leaders a framework for managing cyber risk, covering strategy, people, incident response, and assurance.

• Software Security Code of Practice: Released in May 2025, this code targets software developers and vendors, promoting secure design, deployment, and customer communication. Energy firms procuring software should consider referencing this code in tenders and supplier assessments.

• AI Cyber Security Code of Practice: Published in January 2025, this code addresses risks unique to AI systems, such as data poisoning and model manipulation. Though aimed at developers, energy companies using AI should consider the code in vendor diligence and risk management.

The Cyber Security and Resilience Bill represents a proactive step toward safeguarding the UK’s energy infrastructure against increasingly sophisticated cyber threats. By expanding regulatory scope and introducing practical guidance through Codes of Practice, it is hoped the industry will build a more resilient digital foundation for the energy sector and beyond. 

Want to know more?

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

Brodies

Martin Sloan, Brodies LLP

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The Demographic Cliff: Managing the ‘Great Crew Change’ through Digital Transformation

There is a growing belief that the oil and gas sector is confronting a significant operational challenge as time rumbles on and the intersect between convenience (via technology) and traditional expertise (via experience) draws closer.

Ahighly experienced workforce reliant on the tools of yesteryear are approaching retirement, creating a "Great Crew Change" that threatens to remove decades of invaluable, often undocumented, operational knowledge from the industry. The "Great Crew Change" refers to a significant demographic shift in the industrial workforce - creating a critical knowledge gap, as decades of undocumented, hands-on expertise and institutional memory are at risk of being lost permanently.

Data indicates the gravity of this shift. For example, in the North Sea, the average age of the core offshore workforce in 2021 was marked as 44.1 years old, with 18% of personnel now over the age of 60, while only 12% are between 16 and 29 (ECITB, 2025). This demographic creates risk of a crisis of knowledge translation, where the tacit, sensory experience of veteran engineers is at risk of being lost.

The problem extends beyond demographics, touching upon the fundamental safety and efficiency of operations. The loss of experienced personnel equates to an evaporation of institutional memory; the undocumented workarounds, the intuitive "feel" of equipment, and the unwritten history of past incidents and their resolutions. This attrition can be problematic later down the line; as research shows that for employees not directly involved, the memory of a major

Authored by Brendan Rorrison Associate Director (UK Product)

incident can fade almost completely within three years, creating a cycle where hardwon lessons are lost. This issue can then be compounded by the physical state of assets themselves. As infrastructure ages, with many platforms operating beyond their original design life, the degradation of Safety Critical Elements (SCEs) and widespread corrosion mean that such incidents may increase in volume – and without the relevant knowledge, dealing with these could pose a critical threat.

Simultaneously, the incoming generation of digital natives expects modern tools and processes, finding the sector's traditionally paper-based and sometimes archaic work environment unappealing – despite the obvious advantage in understanding every intricacy of a process such inefficient technologies naturally introduce.

Therefore, digital transformation objectives within the sector should focus on creating an integrated digital ecosystem that guides and protects the next generation of offshore workers whilst also retaining and harvesting the key elements of experience in danger of being lost.

In this context, the ‘Connected Worker’ platform emerges not as a luxury, but as an essential technological bridge to ensure safety, retain institutional memory, and secure the future viability of oil and gas operations.

Effectively, A ‘Connected Worker’ in the oil and gas industry is a frontline field operator, technician, or engineer who is equipped with a suite of digital technologies that link them intuitively to real-time data, equipment, and other team members seamlessly. This integration transforms the worker from an isolated individual performing manual tasks into a fully connected, data-enabled hub of information.

Achieving such a transformation in a practical way relies heavily on a shift from screen-based devices and portable hardware that sprung into life in the 2010s, into more intrinsically linked technology adoption through the likes of wearables that don’t distract from the core job being executed but instead offer a level of tracking, monitoring, and seamless integration into O&G workers days’ – whilst silently building up a knowledge base and data reconciliation that offers future value.

The return on investment for such platforms is measured in safety, efficiency, and preservation. Digitised workflows create a verifiable audit trail, ensuring procedural compliance and drastically reducing human error. The ability for experts to provide remote support minimises the time personnel must spend in hazardous areas, while biometric monitoring allows for proactive safety interventions. Efficiency gains are substantial and McKinsey estimates that such digital tools can reduce operational expenditures by 20-25%. An exemplar Petrofac project for bp reduced a maintenance backlog by 3,000 work-hours using a connected worker solution.

Most profoundly, and critically when considering the original problem discussed, the system captures institutional knowledge. Every remote expert session is recorded, and every digital procedure codifies best practice, creating a living, evolving digital history of the asset. This transforms individual experience into a permanent, searchable corporate asset, accelerating the competency of new hires and solving the knowledge retention crisis.

For industry leaders, the investment is not a cost but a foundational component of digital transformation. The companies that empower their workforce with these tools will not only become the safest and most efficient operators but will also ensure that the future of the workforce can rely on a suitable level of knowledge transfer to guarantee future successes. 

Weatherford Awarded Drilling Contract for Mexico Deepwater Oil Project

Weatherford International plc said it was awarded a “significant” contract to deliver managed pressure drilling (MPD) services for the Trion project, a deepwater oil production project in Mexico operated by Woodside Petróleo Operaciones de Mexico.

The multi-year contract includes MPD services for an initial eight wells with the potential to expand to 24 wells, the company said in a news release. Financial terms of the contract were not disclosed.

As part of the project, Weatherford said it plans to deploy its Victus intelligent MPD system, which it describes as a solution “designed to enhance drilling safety, efficiency, and performance”. The solution features algorithm-driven pressure control, real-time downhole data for automated responses, and the industry’s first field-proven deepwater riser system for floating rigs, according to the release.

The Trion project is located in deepwater about 8,200 feet (2,500 meters) in the Gulf of America, approximately 112 miles (180 kilometers) east of the coast of Tamaulipas and 18.6 miles (30 kilometers) south of the US-Mexico maritime border, the release said.

Trion is a joint venture between Woodside Petróleo Operaciones de México, S. de R.L. de C.V., who serves as the operator with a 60 percent interest, and Petróleos Mexicanos (PEMEX) with 40 percent.

The contract award “reinforces Weatherford’s market leadership in high-performance MPD and expands its presence in Mexico’s offshore energy sector,” the company said.

Weatherford President and CEO Girish Saligram said, “We are proud to support Woodside Energy on this historic project. The Trion development represents a defining moment for Mexico’s energy sector, and Weatherford is honored to contribute with trusted MPD technologies that improve safety, efficiency, and well delivery. This award further strengthens our position as a trusted partner for complex offshore operations”.

Second-Quarter Results

In the second quarter, Weatherford reported revenue of $1.2 billion, an increase of 1 percent sequentially and a decrease of 14 percent year over year. Operating income was $237 million, an increase of 67 percent sequentially and a decrease of 10 percent year over year. Net income for the quarter was $136 million, an increase of 79 percent sequentially and an increase of 9 percent year over year.

Saligram said in a statement, “Our core operating markets continued to exhibit activity slowdown during the quarter, driven by geopolitical events, supply-demand imbalance concerns, and trade uncertainties. Despite these structural headwinds, the One Weatherford team delivered second-quarter results in line with expectations, reflecting disciplined execution and operational efficiency in a distinctly softer market. The sequential performance demonstrates strong fundamentals and the resilience of our operating model”.

“Revenues increased and adjusted EBITDA was flat despite the previously announced divestiture of certain businesses in Argentina. Adjusted Free Cash Flow also increased, even as receivables continued to build in Latin America due to lack of payments in Mexico. This performance underscores the strength of the new Weatherford operating paradigm and marks a positive departure from past responses to prior market cycle inflections,” he added.

Weatherford’s North America revenue was $241 million, down 4 percent compared to the previous quarter, “primarily from lower Wireline activity in Canada Land, partly offset by higher Cementation Products and Liner Hangers activity,” the company said. The North America segment decreased 4 percent from a year ago, primarily from lower activity across all the segments, partly offset by higher activity in the US offshore segment.

The company’s International segment revenue of $963 million was an increase of 2 percent sequentially and 16 percent year-over-year, the company said in its earnings release. 

Saipem secures Scarabeo 8 contract extension with Aker BP until 2027

Aker BP has exercised the option to extend a contract with Saipem for the semi-submersible drilling unit Scarabeo 8 until 31 December 2027.

The extension is a direct continuation of the previous one-year contract and solidifies the ongoing collaboration between the two companies.

The contract was originally awarded by Aker BP to Saipem for a drilling campaign for a three-year period in March 2022. The $325m (€284.88m) contract included the option of two one-year extensions.

The Scarabeo 8, a sixth-generation drilling unit owned by Saipem, will continue to perform drilling activities for Aker BP offshore Norway. Designed to withstand challenging offshore conditions, the derrick deep-water unit is equipped with dynamic positioning and advanced mooring systems, adhering to the highest regulatory standards.

Saipem’s Scarabeo 8 drilling rig was previously employed on various projects with major oil companies across the Norwegian Continental Shelf (NCS), including the Barents Sea.

ConocoPhillips Awards Halliburton Multi-Year Well Stimulation Services Contract in the North Sea

ConocoPhillips Skandinavia AS (ConocoPhillips) awarded Halliburton a contract to deliver comprehensive well stimulation services to improve well performance and reservoir productivity. The contract spans five years and includes three optional extension periods.

Under the agreement, Tidewater’s vessel, North Pomor, will be transformed into an advanced stimulation vessel designed to efficiently deliver offshore well stimulation services in the North Sea. The improvements will include Octiv® digital fracturing services to maximize stimulation equipment performance and operational efficiency.

“We are pleased to strengthen our longstanding relationship with ConocoPhillips through this important award,” said Mark Dawson, senior vice president, Halliburton

Completion and Production division. “This contract win complements our extensive experience in well stimulation and highlights how we execute globally. The combination of our latest technology and our focus on automation and safety is how we maximize value for our customers.”

The contract award highlights Halliburton’s leadership in stimulation services and its strategic focus to deliver integrated solutions for complex offshore environments. 

In a press release, Saipem said this contract extension is a testament to the unit’s high performance and Saipem’s commitment to safety and efficiency.

In July 2024, Aker BP and its partners announced a gas discovery in an exploration well, drilled with the Scarabeo 8 rig in the Barents Sea, nearly 300km off Norway’s northern coastline.

Designated 7324/8-4 (Hassel), the discovery followed the initial exploration effort at well 7324/6-2 in production licence 1170.

Saipem provides engineering services for the design, construction and operation of complex energy infrastructure and plants, both offshore and onshore.

With an employee base of 30,000, the company operates in 50 countries through six business lines: Asset Based Services, Drilling, Energy Carriers, Offshore Wind, Robotics & Industrialized Solutions, and Sustainable Infrastructures. 

INPEX Masela Awards Major FEED Contracts for Abadi LNG Project

Progress is being made on the Abadi LNG project in Indonesia, as INPEX Masela, a subsidiary of INPEX, has announced the awarding of major contracts for the front-end engineering and design (FEED) phase.

The project, which incorporates a carbon capture and storage (CCS) component, is moving forward following the Indonesian government’s approval of a revised development plan in December 2023.

Contracts were awarded for three of the four primary FEED packages. For the floating production, storage and offloading (FPSO) unit, Saipem Indonesia and Technip Engineering Indonesia will each lead a consortium in a “dual-FEED” process to enhance competition. Worley SEA Indonesia has been selected to handle the subsea umbilicals, risers, and flowlines (SURF) and gas export pipeline (GEP) packages. The final contract for the onshore LNG plant (OLNG) has not yet been awarded.

The Abadi LNG project is a joint venture between INPEX Masela (65%), Pertamina (20%), and Petronas (15%). With an anticipated annual production of 9.5 million tons of LNG, these FEED activities are a critical milestone toward reaching a final investment decision for this significant energy venture. 

Well-Safe Solutions Secures Landmark Multi-Year Contract with EnQuest

Strategic partnership strengthens UK decommissioning sector and ensures vital North Sea supply chain resources into the next decade

Well-Safe Solutions has been awarded a landmark multi-year contract by leading independent operator EnQuest, representing a significant milestone in the company’s growth journey and reinforcing its status as one of the most trusted players in the UK decommissioning market.

The firm scope of work is expected to generate revenue in excess of $45 million and will be delivered using the Well-Safe Defender. It includes a minimum of 100 days of activity in 2026, followed by at least 130 days in 2027. Crucially, the agreement provides options for further activity stretching from 2028 through to 2034, creating a multi-year strategic partnership that will help secure vital supply chain capacity in the North Sea well into the next decade

Supporting industry transformation

The award reflects Well-Safe Solutions’ ongoing evolution as a business. In early 2025, the company broadened its service offering to provide full well lifecycle support, responding to the growing demand for integrated, multi-phase campaigns. This strategic shift positioned Well-Safe to better meet client expectations for efficiency, predictability, and value creation across the entire decommissioning process.

Phil Milton, Chief Executive Officer at WellSafe Solutions, commented:

“This contract is a testament to the trust our clients place in us and the consistent performance of our teams. It marks a pivotal moment in our journey and sets the tone for the next phase of our growth.”

Market conditions driving demand

Although 2025 remains a challenging year for the sector, the award represents a turning point for both Well-Safe and the wider industry. Market forecasts indicate a substantial increase in demand for decommissioning capacity from 2026 onwards. At the same time, the supply of mobile offshore drilling units (MODUs) has tightened considerably.

Currently, only seven semi-submersibles are located in or near the UK region, with many already committed to long-term contracts or in stacked condition. This scarcity of assets has heightened the need for reliable, specialist decommissioning solutions such as those offered by Well-Safe. By securing long-term partnerships, both operators and contractors can mitigate the risks associated with constrained capacity and ensure continuity of critical decommissioning programmes.

Chris Hay, Chief Commercial Officer at WellSafe Solutions, said:

“This contract award reflects not only WellSafe’s technical capabilities but also its ability to respond to market needs with agility. We’re proud to support EnQuest in this critical campaign and look forward to delivering a safe and efficient operation.”

Proven operational excellence

Well-Safe has built a strong track record over the past three years, successfully executing multiple decommissioning campaigns across the UK Continental Shelf. Both the WellSafe Defender and the Well-Safe Protector have played central roles in these projects, reinforcing the company’s reputation for safety, efficiency, and operational reliability.

Since its mobilisation in April 2023, the WellSafe Defender has consistently delivered top-quartile performance. Rig uptime has

remained above 98%, thanks to the expertise and dedication of both offshore crews and onshore support teams. This performance record provides clients with confidence that Well-Safe can execute complex projects to the highest standards, even under challenging market conditions.

EnQuest’s commitment to decommissioning

EnQuest also highlighted the importance of the collaboration. Steve Bowyer, EnQuest’s North Sea Managing Director, said:

“EnQuest is delighted to have chosen WellSafe Solutions to support the next phase of our Group decommissioning plans. Having completed the plugging and abandonment of more than 35% of all wells decommissioned across the northern and central North Sea over the past three years, EnQuest is proud to be one of the most prolific decommissioning operators in the region. We look forward to executing the upcoming activity safely and efficiently alongside the Well-Safe team.”

EnQuest has established itself as a leader in decommissioning, employing innovative technologies and operating techniques to deliver top-quartile performance. By partnering with Well-Safe Solutions, the company is ensuring continuity in its longterm programme while helping to maintain North Sea supply chain resilience.

Looking ahead

This multi-year award cements Well-Safe Solutions’ role as a trusted partner for operators across the UKCS and positions the company at the forefront of a sector preparing for a sustained wave of activity. It also signals growing confidence in the future of the UK decommissioning market, as operators and contractors work together to safely and efficiently retire ageing infrastructure while supporting the transition to a lower-carbon energy system. 

Shelf Drilling Announces New LongTerm Contract in Dutch North Sea

Shelf Drilling, Ltd. announced that a subsidiary of Shelf Drilling (North Sea), Ltd. (“Shelf Drilling North Sea” or “SDNS”) has secured a contract for the Shelf Drilling Winner jack-up rig with Tenaz Energy Corp. (“Tenaz Energy”) for operations in the Netherlands. The firm term of the contract is one year, with an option for Tenaz Energy to convert the term to three years within the first six months of operations.

The operations are expected to commence in October or November 2025, shortly after completion of the rig’s current contract in Denmark.

This award represents Shelf Drilling’s first contract in the Dutch energy sector, where offshore activity is scaling up following the government’s renewed focus on strengthening domestic gas production. Tenaz Energy

became the second-largest operator of natural gas assets in the Dutch North Sea earlier this year through its acquisition of Nederlandse Aardolie Maatschappij B.V. (“NAM”), formerly a 50/50 joint venture between Shell PLC and ExxonMobil Corporation.

Greg O’Brien, CEO, commented: “We are very pleased to announce this contract for the Shelf Drilling Winner and to establish our partnership with Tenaz Energy in the Netherlands. This award marks a significant milestone for Shelf Drilling as we expand our footprint into a new and active segment of the North Sea. We appreciate the opportunity to support their multi-year development program and are fully committed to delivering safe, efficient, and sustainable operations for Tenaz Energy.” 

JBS secures first Sea Axe contract in South Korea

JBS has secured its first Sea Axe contract in South Korea, supporting the Yeonggwang Nakwol Offshore Wind Farm project.

Working with Haechun, the Sea Axe spread –equipped with an electric HPU – will carry out underwater cable burial operations to a depth of two metres.

The scope includes 44km of 234mm export cable and approximately 164km of inter-array cable for the 364.8MW development.

Jo McIntosh, Sales & Marketing Director at Jbs, said: “This is fantastic news for Jbs and we are looking forward to working with the talented team at Haechun. This milestone project strengthens our operations in Asia, where we also deliver and install blast containment solutions and screw conveyors.”

Jbs has delivered projects in 80 countries and works across numerous sectors including energy, marine and space.

Known for its innovative Sea Axe technology, Jbs provides efficient, environmentally friendly subsea excavation solutions, reducing deck space requirements and enhancing safety.

The company also offers custom fabrication projects for the energy sector, including deployment frames, and supplies patented blast containment products for fire and arc flash protection.

The firm’s screw conveyors, including dual drive options, serve clients worldwide, supporting operations in energy and industrial sectors.

Jbs won the Going Global honour at the 2023 Northern Star Business Awards, organised by Aberdeen & Grampian Chamber of Commerce. 

Allseas vessel removes giant North Sea Heather A topsides

The platform decommissioning and recycling project involved three years of preparation, including structural modifications and offshore work, culminating in a 14-second lift.

Allseas Pioneering Spirit vessel has completed a single-lift removal of the 15,300mt topsides from the Heather Alpha platform, 460 km northeast of Aberdeen in the UK northern North Sea, according to an Aug. 14 Allseas news release.

It was the largest planned single-lift operation in the North Sea this year, according to a separate Aug. 14 press release by EnQuest, operator of the Heather Field.

The 14-second lift followed three years of detailed engineering, planning and offshore preparation under a collaboration between EnQuest and various contractors.

Allseas started its preparations for the task last year, installing custom-made lift points on the topsides, also performing structural strengthening, caisson works and separation cuts. Much of this activity took place while the platform was still manned.

Early this year, Allseas’ teams returned to complete the underdeck scopes related to leg cutting and separation.

The teams worked alongside specialist rope access crews to address weather and operational constraints to keep the project on schedule.

“Pioneering Spirit completed the lift in around 14 seconds, but that astonishing reality was only made possible by three years of meticulous planning, engineering and preparation works.

After almost 50 years of operations in the North Sea, Heather Alpha’s legacy is to be an exemplar of a best-in-class decommissioning project, from inception to the responsible recycling of its materials.”

—EnQuest Decommissioning Director John Alla

The topsides were due to be transferred to Allseas’ Iron Lady cargo barge for towing to the M.A.R.S. disposal yard in Frederikshavn, Denmark. There, the structure will be dismantled, with more than 95% of materials and other items set to be recycled and repurposed.

Heather Alpha was an integrated drilling, production and living quarters platform. According to the UK’s North Sea Transition Authority, the topsides comprised three decks, supported by an eight-legged tubular steel frame jacket in 143 m water depth. 

North Sea Operators Release New Tenders

EnQuest, Dana Petroleum, Neo Energy, and Petrogas—have initiated a flurry of new tenders for decommissioning projects.

EnQuest is at the forefront with four decommissioning projects. The company’s work on the Heather field includes a sub-£25 million contract for seabed clearance and debris removal, with a revised tender date of January 1, 2026. EnQuest is also exploring options to decommission four wells across its Alma Galia, Don, and Broom fields.

Dana Petroleum is seeking contractors for its Western Isles decommissioning project. The company intends to hire rigs for a planned 80-day period in 2027 to perform reservoir isolation on seven wells split between the Barra and Harris fields.

Neo Energy has issued a tender valued at over £25 million to plug and abandon 19 subsea wells across its Donan, Balloch, and Lochranza fields. This work is set to begin in the first quarter of 2026, with the tender scheduled for release on December 31, 2025.

Petrogas is also contributing to the activity with three contracts for its Abbey and Baker Fields. One major contract, valued at over £25 million, covers subsea EPIC work and has a tender date of November 30, 2025. Two smaller contracts, both under £25 million, will provide pre-FEED and FEED engineering services, with tender releases planned for September 1, 2025, and October 1, 2025, respectively.

CNOOC has also announced its potential well intervention plans for 2026. The company is offering 31 tenders for activities such as logging, repairs, and surveillance across the Scott, Buzzard, and Golden Eagle fields. The work is scheduled for the first quarter of 2026, with no specific contract values provided.

This simultaneous activity in both decommissioning and new energy projects underscores the ongoing transition and evolving priorities within the North Sea’s offshore industry. 

Kent wins Australian offshore decommissioning gig

Host government responsible for decommissioning the Laminaria-Corallina oilfields after liquidation of former operator NOGA

Integrated energy services company Kent has won a new technical advisory services contract from the Australian government to support the permanent plugging and abandonment of the Laminaria-Corallina oilfields in the Timor Sea.

The contract also includes advisory services for the safe removal of associated subsea infrastructure.

Under the initial two-year contract, Nesma & Partners-backed Kent will deploy a multidisciplinary team of technical and regulatory experts to provide strategic and operational support throughout the planning and execution of the decommissioning.

The value of the contract was not disclosed.

“Our advisory team, with deep roots in Australia and the UK, is energised by this opportunity to help shape the future of offshore decommissioning,” commented Michael Costello, executive vice president — development, APAC & Americas at Kent.

Building on existing work on the Northern Endeavour floating production, storage and offloading vessel, the contractor said the latest award underscores its position as a trusted decommissioning partner with a deep commitment to regulatory compliance, environmental stewardship and technical excellence.

The Northern Endeavour FPSO is permanently moored between the Laminaria and Corallina fields in the Timor Sea. Following the liquidation of its former operator, Northern Oil & Gas Australia (NOGA), the facility was transferred to the ownership of the Commonwealth of Australia.

The safe decommissioning of the FPSO and associated infrastructure is a key priority under the government’s broader strategy for responsible offshore oil and gas transition, noted Kent. This includes full lifecycle management of offshore assets and a commitment to protecting Australia’s marine environment through safe, sustainable decommissioning practices. 

EnQuest completes UK North Sea topsides removal

The 15,300 tonne topsides is the heaviest single lift removal scheduled for this year

EnQuest has completed the removal of topsides from its Heather Alpha platform in the UK North Sea, the London-listed operator said on Thursday.

Allseas’ giant heavy lift vessel, the Pioneering Spirit, carried out the removal with the 15,300 tonne topsides the largest single lift removal scheduled for this year, EnQuest said on Thursday.

“The Pioneering Spirit completed the lift in around 14 seconds, but that astonishing reality was only made possible by three years of meticulous planning, engineering and preparation works,” said EnQuest decommissioning director John Allan.

“After almost 50 years of operations in the North Sea, Heather Alpha’s legacy is to be an exemplar of a bestin-class decommissioning project, from inception to the responsible recycling of its materials.”

Installed in 1977, EnQuest gained the greenlight to end production and decommission the platform in May 2020.

The Heather topsides will be dismantled in Frederikshavn, Denmark, with 95% of the structure expected to recycled and repurposed.

EnQuest has plugged and abandoned more than 80 North Sea wells over the past three years as part of plans to decommission its Heather, Broom, Thistle, Deveron, Alma, Galia and The Dons fields. 

UPCOMING GLOBAL EVENTS

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Transforming

As the offshore energy sector accelerates its digital transformation, technology is playing an increasingly central role in improving operational efficiency. This is particularly evident in crew travel and logistics, where managing complexity, cost, and compliance remains a constant challenge. ATPI is addressing these issues through two proprietary platforms, CrewHub and CrewLink, developed specifically for the needs of the offshore and energy industries.

CrewHub: Simplifying the Booking Process

ATPI CrewHub is a booking platform designed to reduce the complexity of group travel in the offshore sector. Tailored to the energy industry’s unique requirements, it enables users to arrange multi-origin, multi-destination itineraries through a straightforward interface with just five required input fields.

By streamlining the booking process, CrewHub helps reduce reliance on email threads, spreadsheets, and disconnected systems. Users report booking time reductions of up to 60%, allowing teams to focus on highervalue tasks. Whether organising a deployment involving multiple countries or managing recurring crew rotations, CrewHub brings all logistics into one place.

The platform offers flexible filtering, by speed, price, or operational preferences, supporting offshore-specific considerations such as remote destinations and last-minute changes. With options to manage up to 20 route combinations per booking, CrewHub accommodates complex mobilisations while helping operators monitor and manage travel spend effectively.

CrewHub also supports direct control by users, allowing them to create, amend, or cancel bookings instantly without third-party intervention. This autonomy can improve responsiveness, particularly in time-sensitive or changing operational contexts.

CrewLink: Centralising Crew Management for Total Control

While CrewHub simplifies the booking process, CrewLink addresses the broader operational challenges involved in managing the entire lifecycle of crew logistics. Designed to handle the ongoing operational demands of maritime and offshore environments, it brings together scheduling, compliance tracking, communication tools, and wellbeing oversight into a single, integrated platform.

In offshore environments where work often takes place in remote or high-risk locations, duty of care extends beyond regulatory compliance. It involves ensuring that workers are supported through clear communication, safe scheduling practices, and responsive planning. CrewLink incorporates these elements by offering real-time visibility into crew movements, enabling operators to respond quickly in the event of disruptions such as extreme weather, logistical delays, or medical issues.

The platform’s rostering tools support more sustainable planning by helping coordinators avoid fatigue risks, ensure rest periods, and prioritise direct travel routes when feasible. CrewLink also allows planners to consider availability, qualifications, and individual preferences, which can contribute to more consistent deployments and reduce administrative overhead.

Communication features built into the system help maintain contact with travelling personnel, facilitating timely updates and support when needed. In operational contexts where conditions may change quickly, the ability to stay connected and informed is key to maintaining safety and coordination.

By bringing these functions into a central platform, CrewLink aims to support more efficient logistics while reinforcing the importance of crew wellbeing as part of daily operations.

The Future of Offshore Travel

Together, CrewHub and CrewLink offer an integrated approach to offshore crew travel and logistics. CrewHub focuses on simplifying and accelerating the booking process, while CrewLink supports long-term planning and oversight. By addressing both the tactical and strategic aspects of crew movement, these platforms help operators improve efficiency, maintain compliance, and better support their workforce in demanding environments.

As project requirements evolve and global operations expand, these tools provide a foundation for more responsive and informed decision-making in offshore travel management.

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

Empowering a Safe, Skilled, and FutureReady Workforce

The global, not-forprofit skills authority for safety-critical industries.

At OPITO, our mission is clear – to be the leading global skills authority for safety-critical industries. Our purpose drives us to provide expertise and solutions that elevate safety, skills, and competence across a global workforce, creating a safer and more skilled future for all.

We work with governments, industry, and training providers to shape standards, drive workforce development, and deliver trusted qualifications across high-risk sectors worldwide.

From global safety standards and qualifications to future-focused initiatives like My Energy Future and the APTUS apprenticeship programme, we’re investing in the talent of tomorrow - ensuring workers are equipped, empowered, and ready to thrive in an evolving energy landscape.

Together, we’re building a safer, skilled future.