Aker BP has entered into a strategic partnership agreement with Viridien to improve productivity in exploration and field development on the Norwegian Continental Shelf (NCS). 

The agreement establishes a long-term framework for collaboration within multi-client ocean bottom node (OBN) seismic acquisition, seismic imaging, and technology development, where the goal is to build an integrated, end-to-end seismic workflow from seismic acquisition to  subsurface image. 

For Aker BP, the partnership is about increasing productivity to support Aker BP’s ambition to deliver profitable and sustainable growth on the Norwegian Continental Shelf. Viridien’s advanced imaging and processing capabilities enable faster and more accurate subsurface insights, while multi-client OBN coverage supports larger scale exploration. Aker BP sees ocean bottom node seismic as a key enabler for improved imaging and higher-quality subsurface data, both in exploration and field development. 

“Together with Viridien we will further strengthen our capabilities in seismic acquisition, imaging, and processing to improve decision quality and unlock greater value from Aker BP’s portfolio. We furthermore expect to move faster from data acquisition to decision-making, reducing cycle times and enabling more efficient exploration and field development”, Petter Sørhaug, SVP Exploration & Reservoir Development in Aker BP, comments.  

The newly entered strategic partnership with Viridien builds on a long and solid cooperation and reflects Aker BP’s broader strategy of leveraging strategic partnerships to drive performance and innovation across the value chain. Together, partnerships with companies such as PXGEO and Viridien enable Aker BP to accelerate productivity in exploration and field development by turning seismic data into better decisions and higher-value opportunities.

How do we inspect a platform where all access is via gangway from a vessel, and where every offshore visit is both time-consuming and costly? At Fenris, we are now testing the use of robotics for inspections and data collection as a direct response to future operational ambitions.

Fenris is one of two new platforms in the Valhall PWP-Fenris project, designed to ensure stable and high production from the Valhall field for many years to come. The platform was recently installed offshore and is expected to start production in Q3 2027.

On the Fenris platform, we have now initiated a pilot where a robot is used for observations, inspections, and data collection offshore. The goal is not to introduce technology for its own sake, but to identify solutions that create real value—operationally, in terms of safety, and organizationally.

Watch the video showing how the robot is used on board Fenris.

A response to Fenris’ unique framework conditions

Fenris will be an unmanned installation (UI), with all access provided via gangway from a Service Operation Vessel (SOV). This ensures high safety but also limits flexibility and entails significant costs related to mobilizing personnel offshore.

The robotic solution has been developed specifically to address these challenges. With the Taurob robot, Aker BP can carry out inspections and collect data without physical presence on the platform. This enables rapid response to deviations while reducing the need for offshore mobilization.

In short: the robot is a tool that directly reflects how Fenris is designed and will be operated.

Starting where risk is low, but learning is high

The pilot is conducted prior to the start of production, where risks are manageable and the potential for learning is high.

At this stage, we are testing whether the technology performs as intended and how the interaction between people, technology, and work processes functions in practice. Key areas of focus include the robot’s robustness in varying weather conditions, communication and availability, and not least how the solution integrates with existing offshore and onshore workflows.

The pilot setup allows for short learning loops and the ability to adjust both scope and ambition along the way, ahead of any potential scaling. This approach builds digital competence step by step.

From pilot to operations—and further scaling

Fenris also serves as a test laboratory for future operating models. The ambition is clear: if the pilot proves successful, the solution will be carried forward into the operational phase.

This is particularly relevant as Fenris produces from a high-pressure/high-temperature (HP/HT) reservoir. The long-term objective is to minimize interventions while maintaining close and intelligent monitoring. Early detection of anomalies can deliver significant value in terms of regularity, safety, and cost efficiency.

Over time, the robot may be used for routine inspections, condition monitoring, and support during incidents. The experience gained from Fenris will also be transferable to other unmanned installations, such as the Yggdrasil field’s Munin platform, and potentially to other normally unmanned facilities and new ways of working—such as remote support or “night operator” functions on projects like PWP. The learnings will also be relevant for future developments and existing brownfield installations.

Digitalization in practice, not just on paper

The use of robotics at Fenris is a tangible example of Aker BP’s ambitious digitalization strategy. Here, new solutions are tested in real operations, with controlled risk and a clear objective of long-term gains.

The project aligns with the ambition of leading operations of unmanned installations, as well as the company’s focus on data, remote operations, and autonomy.

What does success look like?

The pilot will be evaluated in a structured and transparent manner, based on clear criteria such as reliability and availability, usability for offshore and onshore environments, HSE impact, and cost-benefit.

Equally important is identifying what does not work and what needs to change before any potential continuation. All learnings—including those that fall short—will be shared across the organization.

On Wednesday morning, the Aker Humanoid Robot was launched at Akerkvartalet at Fornebu. It serves as a clear illustration of how artificial intelligence and robotics are becoming an increasingly integral part of the industry.

“This is no longer science fiction. Artificial intelligence and robotics are fundamentally changing how the industry operates, including within Aker companies,” says Øyvind Eriksen, President and CEO of Aker ASA.

He emphasizes that this development is already well underway:

“This is not about what might happen in the future. It’s about what is already happening and how we position ourselves. The technology is here. Our task is to understand it and use it correctly.”

A new leadership reality

For Aker BP, this development is not only about technology, it is about how companies must be led in the years ahead.

“This is not just about technology; we are the last generation of leaders who will only lead people. Future leaders will also lead AI agents, drones, and robots,” says Karl‑Johnny Hersvik, CEO of Aker BP.

The launch of the humanoid demonstrated how these technologies already interact. Stein Danielsen showcased how the robot can move and interact and explained that it can be integrated with other systems such as drones and autonomous solutions.

The technology is not new to Aker BP. It builds on solutions already in use offshore.

“Here, sensors, artificial intelligence, and robotics are combined to improve both safety and efficiency.”

Investing in competence and recruitment

To realize the full potential, Aker BP is investing heavily in competence. The company has recently announced 26 positions within artificial intelligence.

“We want to attract the best talent in the industry. If you want to be part of this revolution, apply,” says Hersvik.

At the same time, Aker is launching a group-wide training program in artificial intelligence for all employees.

“This is not about making everyone experts. It’s about making more people confident, curious, and capable of using technology in their daily work. We are in a situation where technology is changing tasks, processes, and decisions across all parts of the business. We must ensure that the entire organization is on board,” says Øyvind Eriksen.

Data as the foundation

A key prerequisite for succeeding with artificial intelligence is access to high-quality data.

“We need to be good at structuring and making all the data we collect available in every possible way, because artificial intelligence depends on good data to work effectively,” says Kjetel Digre, CEO of Aker Solutions.

He also points out that physical infrastructure will evolve to support new technologies:

“We will design environments that are adapted to robots, so that, for example, staircases are particularly suited for them.”

A reminder to evolve

The launch took place next to a full-scale replica of a T-rex, Aker’s deliberate reminder of what happens to those who fail to adapt.

For the Aker companies, the ambition is clear:

The future is being shaped now. And it belongs to those who can combine technology, people, and leadership.

Last week, Minister of Digitalisation Karianne Tung visited Aker BP in Stavanger to see how the future of oil and gas operations is taking shape. The programme included a tour of the integrated operations centre for Yggdrasil. When production from Yggdrasil is operated from the centre in 2027, Aker BP will set a completely new standard for offshore operations.

Yggdrasil is being developed with low-manned and unmanned platforms, resulting in few people offshore and low activity levels. The entire area will be remotely operated from the integrated operations centre and control room in Stavanger. This is made possible through new technology and a unique digital ecosystem.

“From this control room, we can start up, operate and bring the entire processing facility to a safe state without the need for manual offshore operations,” said Kristian Bay Næss, Operations Director for Yggdrasil, during the tour.

The Minister was shown how a small, dynamic team will at all times be present in the integrated operations centre. They will work side by side with control room technicians to proactively optimise production, facility regularity, and ensure safe and efficient operations. All activities will be planned onshore.

During the visit, Bay Næss explained how Yggdrasil is built on data. Thousands of sensors will provide continuous insight into the condition of the facilities. Data is collected and structured through the industrial data platform Cognite Data Fusion (CDF) and visualised using modern tools. Aker BP will also share data seamlessly with strategic suppliers – both human experts and AI agents.

“Our long-term ambition is a high degree of autonomous operations at Yggdrasil. We already have the building blocks for artificial intelligence in place. AI agents will be in use from day one within condition-based maintenance and planning, and we will scale to more parts of the operation as solutions mature. AI will undoubtedly create major opportunities for even more efficient operations in the future,” he said.

The visit reflects Aker BP’s position as a leading digital energy company. In percentage terms, Aker BP has more Copilot users than Microsoft itself – a clear sign that AI is not a side project, but integrated into the way the company works.

The Norwegian continental shelf is mature. To make the remaining resources commercial, a genuine productivity revolution is required. Aker BP believes artificial intelligence is a crucial part of the solution.

For more than ten years, the company has built a real-time data foundation that connects the entire value chain. This is the foundation that now makes it possible to bring AI into the very core of exploration, drilling, operations, maintenance and decision-making.

For Aker BP, the focus is no longer on digitising existing processes, but on building entirely new ways of working – where people, technology and AI agents work together.

What if the fibre cables already lying on the seabed could be used to look into the subsurface?

With the Distributed Acoustic Sensing (DAS) technology, fibre optic cables can function as dense networks of seismic sensors. By sending light signals through the cables, microscopic deformations in the fibre are detected and can be converted into seismic measurements. The result is a continuous receiver system that follows the cable’s position on the seabed or in wells.

This technology opens up a new way to collect seismic data offshore. Instead of installing thousands of sensors on the seabed, we can use existing fibre optic infrastructure.

The need for cost-effective subsurface monitoring is becoming increasingly important. On the Norwegian continental shelf, both the further development of mature fields and new energy forms such as carbon storage and geothermal energy require more frequent and affordable reservoir monitoring.

This is where DAS may play an important role.

From R&D to industrial solution

Aker BP has carried out a series of R&D experiments offshore to qualify the technology as a commercial tool for subsurface monitoring.

The work began with the field trial at Ula in 2022, where a single fibre optic cable was used to collect fibre optic data and compare these with conventional 2D seismic. This was followed by the Poseidon experiment in 2023, where we investigated how acquisition geometry and cable response affect the imaging of the subsurface.

The most advanced tests have been carried out at the Edvard Grieg field in 2024 and 2025, where several fibre cables on the seabed and in the wells were used in the acquisition of fibre optic data from the field.

– DAS has long demonstrated exciting potential. Now it is about making the technology robust enough to function at full scale, in real fields and with real decisions as a consequence, says Espen Birger Raknes, Advanced Geophysicist in EXPRES.

– Through these experiments, the complexity has increased gradually. At the same time, we have built a better understanding of how fibre optic sensors function in practice.

Comparing with conventional seismic

In all experiments, DAS data have been compared with conventional methods such as streamer and ocean-bottom seismic (so-called ocean-bottom seismic (OBS)).

The results show that images of the subsurface can be of comparable quality, even when the data are collected using existing fibre cables.

– For us in Exploration & Reservoir Development, this is an important step towards more continuous and data-driven reservoir understanding. When we can collect data more frequently and at lower cost, we strengthen the basis for decision-making throughout the field’s lifetime, says Helene Hafslund Veire, VP Exploration & Reservoir Development.

The results from the Edvard Grieg experiments show that with DAS technology it is possible to obtain images of the subsurface that are comparable with conventional seismic methods.

A new cost structure for seismic

The greatest advantage of DAS is the potential for significantly lower costs during data acquisition.

Traditional ocean-bottom seismic requires thousands of sensors to be placed and retrieved from the seabed. This involves several vessels, extensive logistics and lengthy operations compared to what is needed to collect DAS data.

With DAS, we instead need:

• access to existing fibre cables
• recording system connected to the cable
• a single source vessel generating seismic signals

Thus, the cost of data acquisition can be reduced by an order of magnitude compared with conventional methods. At the same time, operational complexity is significantly reduced.

More frequent data enables better decisions

When seismic data can be collected faster and more affordably, it also opens up new ways of working.

More frequent measurements provide better insight into how reservoirs develop over time. This makes it possible to detect changes earlier and optimise production more precisely.

The technology may also become important for new applications such as:

• carbon storage (CCS)
• geothermal energy
• monitoring of offshore infrastructure

By using fibre cables that are already installed, we can reduce both the costs and emissions associated with data acquisition.

– This is not about replacing existing methods, but about expanding our toolbox. By combining DAS with conventional seismic, we can develop more flexible and cost-effective monitoring strategies, says Yngve Johansen, EXPRES R&D Portfolio Manager.

Next steps

The work now continues to further develop methods for data acquisition, processing and interpretation of DAS data.

Ongoing analyses of 4D data from Edvard Grieg will investigate whether the technology can be used to map production-related changes in the reservoir.

If successful, DAS could become a central tool for future subsurface monitoring on the Norwegian continental shelf.

Aker BP projects that global oil demand will continue to grow over the coming decade, reaching around 112 million barrels per day by 2035.

In Aker BP’s base case, global oil demand is expected to increase from roughly 105 million barrels per day today to approximately 112 million barrels per day in 2035. This equates to an average annual rise of about 0.7 million barrels per day.

It is the first time Aker BP publish a long-term oil demand outlook. By publishing a quantified base case, Aker BP contributes to the strong analytical tradition in the industry, complementing peers’ scenario work by openly sharing a comprehensive longterm demand study.

The work is conducted by Chief Economist Torbjørn Kjus, which leads the company’s energy market forecasting efforts, and the Markets & Strategic Insights team led by Jostein Magerøy. Modelling is supported by demandside tools from Rystad Energy, used with permission.

Aker BPs oil demand outlook reflects powerful structural forces as population growth, rising incomes, expanding mobility, and increasing materials consumption. All contributing to resilient longterm demand across multiple regions and sectors.

Key drivers include:

• Road Transport: Demand peaks toward 2030 but remains resilient, with consumption in 2035 still higher than today. Efficiency gains and electrification temper growth but do not lead to a rapid decline.
• Petrochemicals: One of the strongest growth engines, driven by rising global demand for materials, plastics, and chemical products.
• Aviation: Increasing global travel and economic expansion support steady, long term consumption growth.
• Other sectors: Maritime, buildings, and industrial use remain broadly stable.
• Power generation: The only major segment showing structural decline as oil continues to be phased out of electricity production.

Aker BP’s long-term oil demand outlook also features a upside and downside scenario.

Under conditions of stronger economic growth and slower efficiency improvements, oil demand could expand more rapidly. This scenario is characterized by:

• Faster than expected aviation and petrochemical growththanexpected aviation and petrochemical growth
• More moderate policy tightening
• Delayed efficiency gains in transport and industry

The result: higher demand growth than the base case and a later peak.

In a world where climate policies accelerate and electrification expands quickly, demand growth would moderate sooner. This scenario includes:

• Faster adoption of electric vehicles
• Accelerated policy action and efficiency improvements
• Weaker macroeconomic conditions
• Potential geopolitical disruptions

Together, these factors point to lower growth and an earlier plateau in global oil demand.

Aker BP’s analysis covers 31 regions and 12 sectors, incorporating macroeconomic trends, technology shifts, policy developments, and refinedproduct demand patterns.

Growth Sectors

• Petrochemicals: Driven by rising global consumption of plastics and chemical feedstocks.
• Aviation: Supported by increasing travel demand and expanding global middle-class mobility.
• Road Transport: Approaches a peak but remains a major consumer through 2035.

Stable Sectors

• Maritime
• Buildings
• Industry: Slightly lower but largely steady.

Declining sector

• Power Generation: The primary source of structural decline as countries transition to other fuels.

With this publication, Aker BP aims to contribute constructively to the global energy dialogue by offering a consistent, transparent, and datadriven perspective on how oil demand may evolve toward 2035.

Read more and download the report here.

Last week, we were pleased to welcome students from the 2nd and 3rd year geoscience classes at Oslo Handelsgym VGS. The students had a unique opportunity to see how geoscience is applied in practice outside the classroom and how their knowledge is highly relevant in our industry.

One of the highlights was the insight into an ongoing drilling operation, where the students were able to follow the activity live and learn more about geosteering and what actually happens when we collect subsurface data. In addition, they met several of our subject specialists who shared insights from their areas.

From geology in Oslo to field development in the North Sea

Mathias Dahl Venberget is a geophysicist and opened the visit with an introduction to the company, the industry and how different disciplines work together.

Geologist Anders Torp gave an introduction to the Solveig field and explained how geoscience plays a central role throughout the field development process, from early assessments to production. Solveig is a subsea tie-back to the Edvard Grieg installation in the North Sea. The students also had the opportunity to see real oil from the exploration well that discovered the Solveig field in 2013.

Jon Halvard Pedersen analyses petroleum systems and took the students back in time, explaining how traces of oil can be detected in the Oslo area, based on the geology and the same principles used in today’s exploration and field understanding.

Practical learning that creates motivation

Steinar Halvdan Hansen Møkkelgjerd is the teacher for the geoscience classes at Oslo Handelsgym. He greatly appreciated giving the students an insight into how the subject is used in practice.

– For the students, it is very useful to be able to see what can be done with the subject in working life. And that it is not just theory on paper, but something we actually use for something meaningful. The hope is that more students will consider an education in the sciences as more relevant, and based on the conversations I have had with students today, I think we may be able to encourage more in a scientific direction, says Møkkelgjerd.

Important to meet young people

For Aker BP, such visits are both important and inspiring. They provide us with the opportunity to show how we work and how theory from school is actually turned into practical decisions in the field. It is also rewarding to meet engaged young people who are curious about how the industry works. We believe that showing relevance early is one of the keys to creating interest and perhaps motivating some to choose a geoscience direction later.

Aker BP has recently carried out an important pilot test of new well technology at the Alvheim field. HIPlog makes it possible to measure production down in the well without stopping production, and has been tested offshore for the first time.

This is the first time the technology has been installed offshore, and the initial results provide valuable insight.

“This project is first and foremost about gaining better insight into what is actually happening down in the well. With HIPlog, we obtain measurements that have previously been difficult or impossible to collect, especially in multilateral wells,” says Morten Hausken, Advanced Reservoir Engineer at Alvheim.

What is HIPlog?

HIPlog is a wireless solution for measuring how oil and gas flow in different parts of a well.

In short, the technology works as follows:

• Small heat sources are permanently installed in the well
• The sources send controlled heat signals into the flow
• Existing temperature sensors register the signals
• The data are used to calculate the production contribution from each branch and zone

Everything happens without cables, without interfering with production, and without additional well operations.

“The fact that we can obtain detailed production information without disrupting operations is ‘the very core of what HIPlog is developed for’,” says Tore Ottesen, Chief Executive Officer at Wellstarter, which delivers the service.

Why is this important?

In modern wells, and especially in multilateral wells, it is often challenging to gain an overview of how production is actually distributed.

HIPlog helps answer questions such as:

• Which branches produce the most
• How production changes over time
• If certain zones contribute less than expected

This insight can be used for:

• improved well management
• more targeted measures at the right time
• increased recovery over the well’s lifetime

“This is a good example of how we work with new technology at Aker BP. It is the result of several years of systematic technology development and qualification,” says Yngve Johansen, Subsurface R&D Manager.

The pilot test at Alvheim

The pilot has been carried out in the Frosk Attic 24/9-M-7 well, which has three branches. In total, nine HIPlog stations are installed, three in each branch.

The first measurement campaign was conducted in November. The analyses show:

• clear and measurable signals from the technology
• production contributions from all three branches
• good measurement quality in two of the branches
• greater uncertainty in one branch, related to well geometry and low rates

“The pilot has provided us with good signals, but also important learning points. Among other things, we see how sensitive the setup is to low rates and distance between measurement points. This is knowledge we take forward,” says Hausken.

More data on the way

This is just the first step. The HIPlog installation is planned to be used over several years, with repeated measurements that will provide a better basis for comparison and clearer trends.

The next measurement round starts at the beginning of January and will contribute to:

• better understanding of the well’s development
• more reliable assessments of production contribution
• higher quality of analyses over time

“It is important to remember that this is early in the well’s life. As we obtain more measurements over time, the data foundation will continuously improve,” says Hausken.

A collaboration built over time

The project is based on several years of thorough preparatory work. The Edvard Grieg team and the JIP collaboration carried out much of the early technology work before the pilot at Alvheim. Aker BP has continued this work through qualification and practical implementation, with a clear focus on reducing risk for the well.

“For us, it has been crucial to test new technology in a controlled way, with a clear focus on well integrity and operational risk. The pilot at Alvheim shows that this is feasible in practice,” says Johansen.

“To be able to develop and test new technology, we are completely dependent on clear sponsors and support from field management. In this project, the support from Anne Skjærstein as sponsor from PE Excellence, the early development work Grethe Schei took part in at the ring source, and not least the anchoring with Alvheim AMT, have all been decisive. When leaders understand technology risk and at the same time dare to pilot new technology, this is how we make it happen in practice.”

The way forward

The pilot demonstrates that HIPlog functions as intended and provides real value. At the same time, this is new technology, and the experiences from Alvheim are expected to be important for further use, both at this field and in future wells.

“This is an important milestone for HIPlog. The fact that the technology is now installed offshore and performs as expected is the result of close collaboration and thorough preparation,” says Ottesen.

More information and updates are expected when the next measurement round has been fully analysed.