Seatrium Ltd. has announced the signing of a MoU with BP Exploration & Production (bp) in preparation for the Tiber Floating Production Unit (FPU) in the US Gulf of Mexico.
Marking the second project for the companies, Seatrium will provide services to carry out the engineering, procurement, construction and commissioning (EPCC) of a FPU designed to support the development of bp’s deepwater assets in the Gulf. The Tiber FPU will be equipped with advanced technologies to enhance operational efficiency and safety.
The Tiber discovery is located approximately 300 miles southwest of New Orleans in the Keathley Canyon.
Seatrium and bp will jointly define the initial works and EPPC scope under the MoU. The contract is subject to the final investment decision by bp which is anticipated for later in the year. The new agreement builds on the existing partnership between the two companies on the Kaskida FPU, which reached final investment decision in 2024.
Reservoir Group, a provider of innovative well intervention services, has successfully deployed its tubing cutting tooling in a variety of sizes and applications for both onshore and offshore environments.
This service, which supports a range of vertical and high deviation wells, is designed to reduce operational costs and bring production back online quickly. The cutting-edge technology, including hydraulic anchor tools, is deployed through coiled tubing, rig drill pipe, and snubbing unit drill pipe.
The diverse range of deployment methods allows Reservoir Group to efficiently service wells in various conditions. In a recent case history involving 11 wells, the company achieved a 100% success rate in tubing cutting operations.
A spokesperson from reservoir Group said, “Our team of technical experts combined with our proprietary products and commitment to customer care have been pivotal in delivering safe, high-quality, and cost-effective solutions.”
Murphy Oil Corporation's fourth quarter production for 2024 from the United States Gulf of Mexico averaged 68,000 barrels of oil equivalent per day (boepd), 80% of which was oil.
This is a slight improvement over the third quarter which recorded 67,000 boepd, comprising 79% oil.
The fourth quarter saw the drilling and completion of the Mormont #4 (Green Canyon 478) well, which was followed by a workover on the Samurai #3 (Green Canyon 432) well.
The well workover was one of the reasons for a production impact of a total 10.8 mboepd in the fourth quarter. A delay in the arrival of the offshore rig to start workover operations on the Samurai led to a production impact of 1.4mboepd from the site.
The Samurai well is tied in with Khaleesi and Mormont fields, resulting into a massive infrastructure that produces more than 15,000 boepd. While the company has seen a successful drilling campaign of Khaleesi #4 well at Green Canyon 389, it also had to conduct repairs to subsea equipment in the Mormont #2 well (Mississippi Canyon 478) to bring it back to production.
A considerable number of workover and sidetrack work kept Murphy busy in 2024, which the company believes are a common occurrence in offshore conditions with high productive wellsites. The Neidermeyer well workeover has been an especially challenging activity for the team.
Usually, reserves-rich, promising subsurface conditions often pose workover requirements to achieve successful production count. There might be a decade-long smooth run or dislocations around minor workover events or well repairing might hit operators every in four-five years; they must be prepared to take these risks and uncertainties before being showered with a good yield.
Successfully in line with all planned workovers in the third quarter, the fourth quarter of 2024 saw a total workover expense of US$30mm for Murphy. This included opertaions of Samurai #3 (Green Canyon 432). For the first quarter of 2025, the company has workover plans on Marmalard #3 (Mississippi Canyon 255), while also bringing the operated Mormont #4 well online.
The Occidental Petroleum-operated Ocotillo #1 exploration well in Mississippi Canyon 40 has been declared a discovery by the partners, more so because it helped bring down exploration expenses. Experts are anticipating it to be a typical Miocene-type tieback opportunity that indicates somewhere between 30 to 60 million barrels.
Overall, Murphy's fourth quarter production for 2024 averaged 175,000 barrels of oil equivalent per day (boepd), which included 85,000 bopd. Its offshore business remained mostly consistent with the third quarter results, producing approximately 75000 boepd, which included 82% oil.
The company is set to spend approximately US$145mn for its 2025 exploration programme, which includes drilling two operated exploration wells in the Gulf of Mexico.
“We have an ambitious exploration programme ahead of us over the next 18 months, with operated wells planned in the Gulf of Mexico, Vietnam and Ivory Coast, in addition to an appraisal well in Vietnam. This optionality across multiple play types in key basins provides significant resource upside for our offshore business. It is an exciting time at Murphy, and exploration will remain a key differentiator and value creator for our company for years to come,” said Eric M Hambly, President and Chief Executive of Murphy.
To know more about the global well intervention scene, click here.
Australia’s leading decommissioning and abandonment conference (D&A AUS 2025) will be opening its doors once again this June for a jam-packed schedule full of more industry updates, case study analyses, networking opportunities and VIP events than ever before.
Taking place at The Crown Perth on 10-11 June, 2025, this year’s edition, once again in partnership with CODA, will shine the spotlight on the region’s regulators, including an in-depth session with NOPSEMA discussing the roadmap for new technology implementation within the Australian decommissioning market.
Attendees will also have the chance to hear the latest updates regarding the notorious Northern Endeavour project in a talk led by the Department of Industry Sciences and Resources, as well as develop a deeper understanding of the on-going environmental research conducted by NDRI, AIMS and ANSTO in a panel session dedicated to identifying current gaps in the research.
Australia’s largest operators will also play an integral role in the conference, including Chevron, ExxonMobil and Woodside who will take centre stage to delve into regional case studies from their current decommissioning portfolio.
This year will feature the debut of the newly revamped expo hall, boasting double the number of booth as previous years and a fresh new look promising to be the one-stop-shop for all decommissioning needs.
As the content value of the conference has continuously elevated, so too have the networking opportunities, allowing delegates to indulge in the VIP treatment. This year, attendees can kick-start proceedings with the Pre-Conference Icebreaker Drinks, garnering new relationships and reconnecting with old faces over cocktails and canapés before toasting to the exciting days to come. D&A AUS 2025 will also once again host its invaluable Networking Drinks after the Day One sessions have ended, allowing delegates to relax, unwind and debrief.
Adding a touch of luxe to the events calendar, this year’s Deluxe Pass Holders will once again be treated to a Deluxe Dinner. The exclusive gathering offers a unique opportunity to connect with fellow delegates in a more intimate setting over a five-course menu. To round out the conference on a high note, VIP Pass Holders will enjoy a night of entertainment complete with a premium drinks package, a three-course meal and plenty of surprises in store.
Featuring 500 delegates, 50 new technology demos, 50 expert speakers, five interactive exhibition and networking spaces and five bespoke networking sessions, D&A AUS 2025 promises to be an unmissable event in the region’s oil and gas calendar.
Considering the high risk of leaving offshore wells abandoned and orphaned in federal waters, the Bureau of Safety and Environmental Enforcement (BSEE) has vowed to strengthen the plugging of orphaned wells and associated pipelines.
According to BSEE's analysis, well decommissioning costs around US$344,000 to US$421,000. Investing an adequate amount in this area would likely help in supporting around 10,500 well-paying jobs annually over the next decade. These jobs would be tailor-made for oil and gas workers as well as additional jobs in the oil and gas inspections workforce to detect harmful methane leaks—which have devastating effects on the environment and people—and survey orphan wells for cleanup.
Although thousands of wells are orphaned or improperly unplugged, a lack of adequate information regarding their exact numbers cannot create specific processes for monitoring these wells, including for their carbon, hydrogen sulfide, and methane emissions. This is why keeping a comprehensive record of the condition and location of all offshore oil and gas wells and facilities and consistent monitoring should continue after decommissioning is complete. Around 18,000 miles of inactive pipelines that are unmapped and unmonitored in the Gulf of Mexico.
According to the Centre for American Progress (CAP), enforcement of existing policies; a robust federal job programme; increasing financial obligations; and a comprehensive record-keeping and monitoring process are considered to be viable approaches to both reducing the negative socioeconomic and environmental impacts of these sites as well as the ease with which they come to exist.
Flow remediation specialist, Pipetech, has announced it will be launching its Downhole Scale Remediation (DSR) technology in the coming months.
The new product, under development for the last two years, is set to redefine wellbore cleaning solutions for the global energy sector while promoting sustainable practices, addressing the industry challenges posed by scale, wax, and other naturally occurring deposits that obstruct fluid flow, compromise production efficiency and create unsuitable surfaces for bridge plugs.
The DSR technology offers a different approach to tackling wellbore scale; instead of using corrosive chemicals, it leverages a rotational high-pressure water-jetting system, which tracks and adapts to a wellbore’s varying inner diameter (ID), delivering precise and effective cleaning for safety valves, side pocket mandrels, and other critical areas, efficiently restoring surfaces to bare metal and thus enhancing production efficiency while significantly reducing environmental impact.
Patented in the UK and US, the technology has achieved proof of concept during qualification trials and has also undergone client trials with leading energy operators. Field trials are set to take place this year to demonstrate the DSR’s superiority over existing chemical and mechanical methods, while global testing is scheduled across redundant wells in the UK, Norway, and other international locations to confirm its adaptability and reliability in diverse field conditions.
Leonard Hamill, Operations Director at Pipetech commented, “The DSR technology represents a major step forward for the energy sector. By combining advanced engineering with an eco-conscious approach, we’re providing a solution that tackles a long-standing operational challenge while aligning with the industry’s sustainability goals. We are proud to lead this innovation and are thrilled by the strong interest we’ve received from major operators, which underscores the DSR’s potential to become a game-changer in flow assurance.”
Expro has announced the continuation of its partnership with Perenco-CCS in the UK, reinforcing its commitment to supporting the gas company’s Southern North Sea (SNS) operations.
The agreement extends a relationship spanning almost two decades and solidifies Expro’s role as a key supplier of well intervention services to Perenco since 2012 when the company started acquiring gas assets in the SNS. Over the years, Expro’s services range has expanded to include well testing and tubular running services.
Both parties state they are “excited to work together on the UK energy transition to enable a bright future for the SNS via low emissions domestic gas supplies and by moving carbon capture from concept to reality.”
The offshore oil and gas industry is experiencing a transformative wave, driven not only by innovations in downhole technologies but also by its increasing adoption of digitalisation.
Across the globe, digital technologies and digitised data are reshaping industries, and oil and gas is no exception. Solutions leveraging IoT technologies, data analytics, and digital twins are enabling operators to harness information more effectively. These advancements are improving productivity and unlocking significant cost savings.
According to SLB, many companies are leveraging digitalisation to enhance their portfolios. SLB, for instance, uses its Intervention Advisor Software to manage risks, cut value chain costs, and improve production. The software offers diagnostic, remediation, and prevention methods tailored to optimise operations and reduce costs per barrel. Additionally, SLB’s recently announced partnership with Geminus AI introduces a physics-informed AI model builder, allowing for real-time optimisation across various outcomes, including operational expenditure reduction, increased productivity, and carbon emissions minimisation. “Geminus’ capability to fuse AI methods with physics-based simulation data will empower customers to quickly and easily create hybrid models of their operating assets that can be optimised in real time against numerous outcomes, such as opex reduction, increased productivity, and carbon emissions minimisation,” remarked Rakesh Jaggi, President, Digital and Integration, SLB.
In the second half of 2023, Silverwell Technology announced it had secured a major contract in Southeast Asia to deploy its digitally intelligent artificial lift (DIAL) system across multiple wells. According to the company, DIAL integrates in-well monitoring with surface analytics and automation to optimise gas-lifted fields remotely, even in challenging environments. Silverwell added that, across a three-year contract, the technology would be deployed in difficult conditions and expressed hopes that its successful completion would encourage broader adoption in the region.
The development of digital tools, especially around data interpretation, is being closely watched in the industry. According to Utama, “Improving the interpretation of logging data with new technology will enable oil companies to make better decisions for their well, especially around abandonment.”
The continued evolution and adoption of digitalisation remain a focal point for the offshore oil and gas sector, driving innovation and efficiency across operations.
Baker Hughes has been awarded a multi-year contract from ExxonMobil Guyana to provide specialty chemicals and related services for its Uaru and Whiptail offshore greenfield developments in Guyana’s Stabroek Block, one of the most prolific oil discoveries of recent years.
The contract includes all topsides, subsea, water injection and utility chemicals for the Errea Wittu and Jaguar FPSO vessels, which are currently under development, and are targeted to begin production in 2026 and 2027 respectively. Baker Hughes has established local supply chains to create a reliable and efficient source of chemicals to address the unique needs of these developments.
Uaru and Whiptail are ExxonMobil Guyana’s fifth and sixth projects in the country, where it has been producing oil for more than five years. The two developments will include up to 20 drill centres and 92 production and injection wells. Each FPSO will have a capacity of 250,000 barrels per day, bringing the country’s total daily production capacity to approximately 1.3mn bbl. According to its recently-released 2024 results, Exxon Mobil achieved record production in Guyana last year.
Since “first oil” at the offshore Liza Phase 1 project five years ago, Guyana is now the third largest per capital oil producer in the world and is seeing its offshore sector expand rapidly, which in turn is spurring significant economic growth in the country.
Baker Hughes has a strong history of localisation in Guyana, opening a multimodal supercenter in Georgetown in 2022. The company also provides a variety of services and equipment to operators in the country, including turbomachinery for ExxonMobil Guyana’s FPSO fleet and production chemicals for the Liza Unity vessel.
“ExxonMobil Guyana and Baker Hughes share a long history of supporting Guyana’s energy sector, and we look forward to working together to write its next chapter,” said Amerino Gatti, Executive Vice President, Oilfield Services & Equipment at Baker Hughes. “Our experience operating across the country’s energy supply chain and unmatched expertise in oilfield and industrial chemicals make Baker Hughes uniquely suited to support complex FPSO operations such as these.”
Halliburton has finalised its acquisition of Optime Subsea, resulting in American giant now owning 100% of the Norwegian company.
Jan-Fredrik Carlsen, CEO of Optime Subsea, said, “Joining Halliburton is a proud moment for Optime Subsea. This acquisition will allow us to scale our innovative technologies, reach new markets, and continue delivering exceptional value to our customers worldwide.”
Since its founding a decade ago in 2015, Optime Subsea has committed to delivering cost-effective subsea solutions to the oil and gas industry, including its flagship technologies Subsea Controls and Intervention Light System (SCILS), and the Remote Operated Controls System (ROCS).
With Halliburton’s global reach and extensive infrastructure, Optime Subsea is now positioned to accelerate deployment of its technology on a larger scale to provide a more robust portfolio of subsea control and intervention solutions.
“As we transition into this exciting new chapter, our commitment to innovation, customer satisfaction, and operational excellence remains unwavering. As part of Halliburton, we look forward to creating new opportunities and delivering unmatched solutions to the energy sector,” commented Carlsen.
The acquisition represents a shared vision between Optime and Halliburton to drive progress and efficiency in subsea operations. The two aim to redefine standards for reliability, sustainability and performance in the subsea industry.
Well-Safe Solutions has received a further contract extension from Eni Energy Netherlands BV to decommission selected subsea and platform wells across the Italian energy giant’s portfolio in the North Sea.
Eni have exercised another 90-day option for the Well-Safe Protector jack-up asset under the new contract. The work will be executed in direct continuation with the previously declared option which commenced in November 2024.
Upon the completion of the latest option for Eni, the Well-Safe Protector will move onto the Spirit Energy contract which was announced in November. By completing the work for multiple operators, Well-Safe Protector will be committed until at least August 2025, with further long-term options agreed with Eni.
The new amendment offers increased flexibility for Eni which has the option to green light an additional 120 days of work to decommission platform wells immediately after the completion of work for Spirit Energy, along with two further options at 180 days each. If these options are exercised, Well-Safe Protector has the potential to remain outside the UKCS until Q4 2026.
Well-Safe Protector has been operational in the North Sea since August 2023, having already decommissioned 25 wells across the Dutch and UK waters for Eni, Ithaca Energy and Neptune Energy.
Phil Milton, Chief Executive Officer at Well-Safe Solutions, said, “Well decommissioning continues to account for a considerable amount of the North Sea’s overall decommissioning activity – with a 50% increase in well decommissioning forecast by OEUK last year.
“Since the Well-Safe Protector first mobilised in August 2023, it has delivered top-quartile operational uptime – ensuring the learnings from continual well decommissioning activity are reinvested into future work scopes. Effective well decommissioning cannot exist without cooperation, and we are looking forward to deepening the partnership we currently enjoy with Eni as we build the foundations of a long-term well decommissioning campaign at this key moment in the North Sea’s development towards a low-carbon future.”
This latest contract continues a period of growth for the business. In November 2024, the company announced two new contracts totalling US$25mn for approximately 170 days of firm work in the North Sea, using Well-Safe Protector and the Well-Safe Defender semi-submersible, for Spirit Energy and an additional global operator.
Identifying the urgency of adequate support for North Sea operators, Houston-based offshore innovator, Trendsetter Vulcan Offshore, has appointed Finlay Johnston to lead business development efforts for the company in the United Kingdom.
“There is a long-term need for expert subsea support services in the UK, and by engaging a local representative, we are strengthening our commitment to the region, providing an avenue for North Sea operators to access our proven solutions, and ensuring the supply of quality service and equipment locally,” said TVO President Jim Maher.
Onboarded via 4C Global Consultancy, where he is a Senior Executive, Johnston will be spearheading TVOs services in the UK region, equipped with a vast range of experiences from commercialising assets to supporting the growth of drilling contractors, well intervention, well abandonment, marine and multi-service companies.
TVO is banking on the reputation of 4C Global Consultancy and Johnston's extensive experience to serve its clients in the UK. "The consultancy has a history of successes that demonstrate their capability, and Finlay’s personal achievements strengthen the value of this partnership,” said TVO Vice President Kevin Chell.
As a local representative, Johnston will supervise TVO's activities in line with Norwegian Shelf Competitive Position (NORSOK) standards and the regulatory requirements of the North Sea Transition Authority (NSTA) to implement the company's expert services such as wellhead cyclic stress reduction, among other offerings. The wellhead is exposed to extreme pressure conditions when massive structures initiate the process of oil & gas extraction. Addressing stress reduction through structural integrity and reliability thus holds immense significance to make the exploration and production process a success.
TVOs other services are aligned with the ambitious targets of conducting the plugging and abandonment (P&A) of more than 200 wells in a year, designed to address the challenges involved.
The North Sea oil & gas scene has witnessed an especially turbulent period since the announcement of the energy profits levy (EPL) in 2022 as a temporary arrangement, but it never went away, with the tax margin seeing a consistent rise with time. To top that, the energy generator levy was announced as well. Under such volatile economic circumstances, TVO's local presence will bring certain relief to regional operators by making its critical technology easily available.
“We ... are continuing to add to our global team,” said Maher on the onboarding of Johnston, which follows the recent appointment of a Country Manager in Australia.
As a commercial leader with more than 25 years of international experience in business development, contracting, and customer relationship management in the energy sector and finance, Johnston has worked with corporate leaders and the C-suite of S&P 500 companies.
“By enhancing the company’s commitment to the region with boots on the ground and aligning with well teams, decommissioning and well management companies, TVO will be able to improve project efficiency with proven solutions that reduce cost and risk for operators in an environmentally sensitive area," he said.
To know more about the well intervention scene in and around the European Union regions, click here.
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