Latest News

• Region: North America
• Topics: Well Intervention
• Date: 11 Feb, 2025

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. 

Workover work

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.

• Region: Australia
• Topics: Decommissioning
• Date: 10 Feb, 2025

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.

• Region: Gulf of Mexico
• Topics: Decommissioning
• Date: 10 Feb, 2025

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.

• Region: All
• Topics: Well Intervention
• Date: 07 Feb 2025

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.”

• Region: Europe
• Topics: Well Intervention
• Date: Feb, 2025

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.”

• Region: Asia Pacific
• Topics: Well Intervention
• Date: Feb, 2025

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.

• Region: Latin America
• Topics: Well Intervention
• Date: Feb, 2025

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.”

• Region: All
• Topics: Well Intervention
• Date: Feb, 2025

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.

• Region: Europe
• Topics: Decommissioning
• Date: Feb, 2025

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.

• Region: Europe
• Topics: Well Intervention
• Date: Feb, 2025

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. 

Relief for local operators

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. 

• Region: West Africa
• Topics: Well Intervention
• Date: Feb, 2025

Baker Hughes has reached an agreement with the Nigerian National Petroleum Corporation (NNPC) and FIRST Exploration & Petroleum Development Company (FIRST E&P) joint venture (JV) to deploy its Leucipa automated field production solution on the JV’s offshore operations in the Niger Delta.

The deployment marks the inaugural adoption of the system in Sub-Saharan Africa. The JV will utilise Leucipa’s core workflows to optimise well performance and enhance efficiency by automating functions including performance analysis, opportunity management and scorecards management.

Real-time data will be provided by the technology which will offer more insightful optimisation opportunities across operations, resulting in enhanced decision-making in the field.

Amerino Gatti, Executive Vice President of Oilfield Services & Equipment at Baker Hughes, said, “Leucipa is enhancing the oilfield to be smarter and more efficient, enabling our customers to maximise the value to their assets. Our collaboration with the NNPC/FIRST E&P JV in implementing Leucipa will support the responsible development of energy resources needed in Sub-Saharan Africa for years to come.”

The automated field production solution assists oil and gas operators in proactively managing production and reducing carbon emissions. By focusing on specific outcomes, Leucipa utilises data to drive intelligent operations to minimise inefficiencies, ensure environmentally sound operations, and assist customers in recovering the millions of barrels that would otherwise remain untapped.

• Region: Asia Pacific
• Topics: Decommissioning
• Date: Feb, 2025

In Asia regulatory change driven largely by environmental concerns has continued apace, notably with the ASEAN Council on Petroleum (ASCOPE) issuing decommissioning guidelines for oil & gas facilities.

Industry sources estimate that around 800 offshore platforms in the Asia Pacific region will enter decommissioning by 2027, at a predicted cost of some US$100 bn. While English law remains a popular choice to govern Asia Pacific decommissioning contracts, it faces stiff competition from other systems.

The dispute resolution clause of BIMCO’s DISMANTLECON form of contract envisages a choice between English, Singapore and US maritime (or New York) law. Historically, English and Singapore law have followed each other closely. However, the common law of penalties is the latest area in which divergence has emerged, with the Singapore Court of Appeal declining to follow the UK Supreme Court’s Cavendish Square decision when examining liquidated damages and forfeiture clauses in oil and gas contracts. Choice of law therefore, has real consequences for businesses engaged in decommissioning.

Net zero also has a profound impact on decommissioning. Despite the Strategy’s change of name, the MER objective remains in place. This is no “keep it in the ground” strategy. What has altered is the way assets are managed in the context of recovery of oil and gas. The updated OGA Strategy is unlikely in itself to accelerate the pace at which assets come forward for decommissioning, beyond the consequences of falling demand (and perhaps prices) flowing from the government’s overall policy of reducing fossil fuel dependence in the downstream economy. Rather, elements of the OGA Strategy may slow the pace of decommissioning.

The Central Obligation is supplemented by a number of detailed provisions on re-use of assets not only for CCS projects but also, 'where appropriate', for 'projects relating to hydrogen supply'. 15 to 17 of the OGA Strategy, headed 'Decommissioning', require relevant persons to demonstrate, before planning decommissioning of infrastructure, that 'all viable options' for its continued use, 'including for reuse or re-purposing for CCS' have been 'suitably explored'. Note the word 'including': potential re-use is not confined to CCS but could also include hydrogen and other clean energy uses such as offshore wind. So, even where an asset cannot continue in economic petroleum use, OPRED may reject a decommissioning programme where the whole or part of the structure may viably support clean energy development.

The OGA may also use its licensing powers to ensure cooperation between asset owners and others, including parties seeking to invest in alternative uses. Postponement of decommissioning will sometimes, but not always, be welcome news to asset owners. UKCS M&A transactions and other contracts will typically be priced on assumptions about the useful life of an asset and the timeframe within which the costly process of decommissioning is expected to take place. Insistence by OGA or OPRED on prolonging the life of an asset with a view to reuse may result in parties discovering they have overpaid into a security arrangement, or finding themselves compelled to negotiate elaborate cost apportionments with incoming investors. Unravelling or altering already complex contractual arrangements to accommodate these changes may prove legally and financially problematic.