Archer, a prominent provider of drilling and well services, has secured a five-year contract with Repsol Resources UK for a range of services, including platform drilling, facilities engineering, coil tubing, wireline services, and downhole well service technologies
The deal also includes an option for a two-year extension.
This collaboration will focus on late-life operations and plug and abandonment (P&A) work across Repsol’s vast portfolio of North Sea platforms, including Piper, Claymore, Tartan, Saltire, Auk, Arbroath, Montrose, Beatrice, and Clyde. A significant aspect of the contract is the P&A scope, which involves around 130 wells.
Dag Skindlo, Archer's CEO, expressed his enthusiasm about the achievement: “We are pleased to strengthen our partnership with Repsol through this major long-term agreement within our strategic focus on P&A services. We have robust technical and attractive commercial offerings within late life and P&A, and our team is committed to delivering operational excellence, innovation, and sustainability in the decommissioning of these assets.”
This contract further establishes Archer as a reliable provider of integrated drilling and well services, with a strong focus on safe, cost-effective operations in the North Sea.
As countries, like Iraq, Oman, Syria, the UAE, and Saudi Arabia ramp up production or restore ageing fields, the demand for specialised operations to maintain, repair, or enhance oil wells is poised for decent growth.
The UAE aims to reach 5 million bpd in crude oil production capacity by 2027, requiring significant upstream development.
For this, ADNOC has partnered with SLB to deploy advanced electric completion technologies across onshore fields, starting with six electric interval control valves in the Bu Hasa field.
These technologies enhance well efficiency and reduce intervention costs, signaling a shift toward smarter, sustainable intervention methods.
Additionally, ADNOC’s US$80bn XRG investment vehicle targets low-carbon and gas projects, which could include interventions to optimise gas wells.
Saudi Aramco’s discovery of 14 new oil and gas fields in the eastern province and Empty Quarter, announced last month, includes fields like Jabu and Ayfan.
Developing these fields will likely require interventions to maximise output, such as acidising or perforations, especially in complex reservoirs.
Moreover, Saudi Arabia’s plan to increase oil production capacity from 2025 to 2027, before stabilising at 12.3 million bpd in 2028, will necessitate interventions to maintain ageing wells and optimise new ones.
Apart from this, OPEC+ plans to increase output by 411,000 bpd next month, which could mean that there will be a pressure to optimise existing wells.
Oman’s oil production is expected to surge to 775,000 bpd next month.
This demands ongoing maintenance to sustain, particularly in mature fields.
Interventions such as hydraulic fracturing and coiled tubing operations are essential to optimise well performance and extend field life.
Oman’s upstream investments signal a robust market for intervention services as the country seeks to solidify its position in global energy markets.
In Iraq, the Dhi Qar Oil Company’s recent initiative to drill 17 new wells at the Gharraf oil field reflects a push to expand production capacity.
New wells frequently require interventions like well stimulation or plugging to address declining output or mechanical issues, creating a steady pipeline of work for service providers.
In a post-Assad Syria, efforts to revive a battered oil sector are gaining traction, with the new government eyeing Azerbaijan’s expertise to rehabilitate fields in northeastern regions.
While exact numbers are unavailable, various estimates have put Syria's current oil production between 90,000 and 110,000 bpd.
This is a major fall from the 385,000 bpd reported in 2010, which could spell a need for well interventions to restore output.
Valaris Limited has been awarded a five-well contract offshore West Africa for drillship VALARIS DS-15
The VALARIS DS-15 is equipped with BOP stacks that comprise 10,1000 psi annulars, seven ram and 15,000 psi blowout preventer (BOP) which are critical for well control.
The US$135mn-worth contract that will span nearly 250 days, is scheduled to commence in the third quarter 2026.
Including upfront payments for rig upgrades and mobilisation, the total contract value does not include the provision of additional services. There are priced options for up to five wells with an estimated total duration of 80 to 100 days.
President and chief executive officer Anton Dibowitz said, “We are excited to have secured another contract for one of our high-specification drillships. As part of this contract, the rig will be upgraded with an enhanced managed pressure drilling system. We believe this contract reflects the market’s preference for contractors that can deliver complex drilling solutions with high-specification, seventh generation drillships. In addition, this contract adds to our presence offshore West Africa, where we are well positioned for future contracting opportunities.”
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Subsea 7 has won a significant contract from Petrobras via a competitive tender, for the development of the Buzios 11 field offshore Brazil
The company will be providing engineering, procurement, fabrication, installation, and pre-commissioning of 112 km rigid risers and flowlines system for the field development.
While the company will be initiating project management and engineering work from its offices in Rio de Janeiro, Suresnes and Sutton, it will handle pipelines fabrication from its spoolbase in Brazil.
Located approximately 180 kms off the coast of Rio de Janeiro, Brazil, at 2,000 metres water depth in the pre-salt Santos basin, activities on the site will take place in 2027 and 2028.
Yann Cottart, Senior Vice-President Brazil and Global Projects Centre West said, "This award again underscores Subsea7’s proven expertise in delivering complex, world-scale size projects, reinforcing our strong execution capabilities and commitment to operational excellence and safety.
"With a solid backlog and a diverse portfolio, we continue to drive value for our shareholders while further contributing to Brazil’s development. We thank Petrobras for their trust and look forward to once again playing a significant role in the success of the Buzios field."
Seamless tubular solutions provider, Vallourec is also contributing in the Petrobras-operated Buzios project.
One of the Gulf of Mexico’s leading late-life decommissioning specialist, Promethean Energy, has completed the decommissioning of offshore orphaned wells in the Matagorda Island lease area.
Steve Louis, SVP of Decommissioning at Promethean, said, “Our team is incredibly proud to have completed this critical work efficiently, safely and ahead of budget. By integrating our expertise, technologies and strategic partnerships, we have demonstrated that decommissioning can be both cost-effective and environmentally responsible.”
The project began with drone inspections, safety preparations and detailed well diagnostics, leading to the lower and upper P&A of the wells. Promethean’s approach aligns with its commitment to leveraging cutting-edge technology to ensure safe and responsible end-of-life asset management.
Clint Boman, Senior Vice President of Operations, commented, “We are advancing standards at Matagorda Island and providing a replicable model for similar projects worldwide. Our focus is – and always will be – raising standards for safety, efficiency and innovation in decommissioning across our industry. For example, we implemented visual intelligence tools to manage safety risks associated with ageing offshore infrastructure addressing a long-standing industry challenge.”
Ernest Hui, Chief Strategy Officer of Promethean Energy, concluded, “Building on our strong execution performance, our strategy is to continue identifying synergies with other asset owners, fostering collaboration, and developing sustainable decommissioning campaigns that drive efficiency across the industry."
Expro Group Holdings N.V., in its financial and operational results for the first quarter of 2025, reported notable progress in offshore well intervention operations across the Middle East and North Africa (MENA) region.
The company posted US$94mn in MENA revenue for Q1 2025—a 1% increase compared to the previous quarter—supported by growth in well intervention and integrity activities in Qatar, enhanced production solutions in Algeria, and expanded Coretrax well construction work.
Significantly, Expro successfully concluded deepwater Tubular Running Services (TRS) for two exploration wells in the East Mediterranean. These operations demonstrated the company's ability to deliver reliable and efficient offshore services under complex conditions, reinforcing Expro’s reputation for safety and technical excellence in deepwater environments.
A major technology milestone in the region was the successful pilot of Expro’s QPulse multiphase flow meter in Saudi Arabia’s Jaffurah field. The system showed strong correlation with traditional test separators, validating it as a standalone, non-intrusive solution for production testing. Portable and environmentally conscious, QPulse enables real-time performance monitoring without production deferrals or safety risks, positioning it as a forward-looking tool in the company’s offshore intervention arsenal.
Segment EBITDA for MENA rose to US$34mn with a margin of 37%, up from 35% in Q4 2024, driven by improved activity mix.
This article is based on Expro’s Q1 2025 report, which outlines operational and technological advancements across multiple global regions.
The decommissioning challenge facing Australia is coming into sharp focus, presenting critical legal and contractual issues for all involved, according to law firm Wotton Kearney (WK).
In a recent update, the firm outlined the scale of the task facing operators, contractors and engineering teams against a regulatory environment that will be watching closely.
Over the next 50 years, Australia is expected to see more than US$40bn in offshore decommissioning activity, with most of that spend focused on well plugging and abandonment, as well as pipeline removal.
Titleholders are legally responsible for the full cost and safe removal of offshore infrastructure under the Offshore Petroleum and Greenhouse Gas Storage Act 2006, and must meet strict environmental and consultation obligations.
“While this signals significant economic opportunities for the broader Australian maritime sector,” WK noted in the update, “in an era when much greater focus and emphasis is placed on the green economy, decarbonising, and prioritising environmentally sound practices over economic expediency, it also raises questions.”
These questions include not only the technical feasibility in carrying out these complex and potentially hazardous operations, but also precisely what the decommissioning and environmental obligations are for operators and infrastructure owners.
“The media has recently focused on some high profile examples, such as Esso’s decommissioning plan for 12 platforms in the Bass Strait, Victoria, with the Maritime Union of Australia raising concerns that not all of the infrastructure will be removed,” the WK update added.
It noted that the discussion around Esso’s proposal has prompted debate as to what the 2006 Act actually permits.
“While decommissioning activities under the 2006 Act cannot commence without the titleholders securing a series of environmental approvals through the National Offshore Petroleum Safety and Environmental Management Authority (NOPSEMA), Esso’s decommissioning proposal includes leaving rigs in place and converting these into artificial reefs. This was previously done in the Gulf of Mexico.”
But the practice of leaving some infrastructure in place has created debate about the environmental implications and whether that breaches any legal obligations, WK added in the update.
In this regard, decommissioning involves a range of “complex and sometimes controversial issues,” WK stated.
Australia, like other nations, also has international obligations as a signatory to the United Nations Convention on the Law of the Sea 1994 (UNCLOS), which is the primary international legal instrument governing decommissioning.
What it means is that “complying with regulatory requirements for decommissioning is far from the straightforward.”
That is purely from a legal and regulatory perspective, without the additional burden from any public scrutiny or reputational risks arising from decommissioning activities.
“It’s therefore crucial to develop an appropriate strategy with appropriate stakeholders, align this with insurance cover, and coordinate execution of this plan with logistic and supply chain suppliers,” WK added.
The law firm is exploring some of these issues in a series on decommissioning to identify key issues for stakeholders and to help navigate the uncertainties ahead.
More than 200 offshore fields comprising of over 1,500 platforms and 7,000 wells are expected to curb production by 2030, signalling an urgent need for clarity in regard to decommissioning regimes.
Despite the task size, only a handful of southeast Asian countries are involved in decommissioning activities, making their overall experience limited. Adding to this challenge, are the following three region-specific issues:
Earlier in the year the Centre of Decommissioning Australia welcomed Simon Kemp as the latest member to its Industry Advisory Committee.
Simon, whose current role is Decommissioning Manager at ExxonMobil Australia, has brought two decades’ worth of industry experience to the role. After spending 23 years with ExxonMobile in diverse roles across offshore projects in the Bass Strait, he brings a wealth of knowledge to the Committee.
Now based in Melbourne, Simon leads the strategic planning for decommissioning ExxonMobil Australia’s Gippsland operations.
Commenting on the new position, Simon said, “I’m looking forward to continuing my work with CODA in this new role, helping advance Australia’s capabilities in responsible and sustainable decommissioning.”
Inching closer towards its goals to hit 300,000 net barrels per day of oil equivalent from the Gulf in 2026, Chevron Corporation has started production from the Ballymore subsea tieback in the deepwater Gulf of America.
The latest in a series of Chevron projects to start up last year, the company expects to produce up to 75,000 gross barrels of oil per day through three wells tied back three miles to the existing Chevron-operated Blind Faith facility.
“Ballymore is an example of how we are leveraging technology and driving efficiencies to help produce affordable, reliable energy from the deepwater Gulf of America, one of the lowest carbon intensity oil and gas producing basins in the world,” said Brent Gros, Vice President, Chevron Gulf of America. “Ballymore, which was completed on time and on budget, brings additional production online without building a new standalone offshore platform. This reduces our development costs and is expected to drive higher returns for shareholders.”
A prominent leaseholder in the Gulf, Chevron is keen on exploring further growth opportunities in the basin. Since last year, the company has started production from its industry-first Anchor project and non-operated Whale project and has been prioritising water injection to boost output at its operated Tahiti and Jack/St. Malo facilities.
Estimated potentially recoverable resources at Ballymore are 150 mn barrels of oil equivalent gross over the life of the project. Ballymore is located in the Mississippi Canyon area in around 6,600 feet (2,000 m) of water, about 160 miles (260 km) southeast of New Orleans. The development is Chevron’s first in the Norphlet trend of the Gulf.
The major's subsidiary Chevron USA Inc is operator of the Ballymore project with 60% working interest, along with TotalEnergies E&P USA, Inc who owns 40% working interest.
Expro Group Holdings N.V., a leading energy services provider, has announced its financial and operational results for the first quarter of 2025, revealing a revenue decline but highlighting technological advancements and new contract wins.
The company reported revenue of $391 million for the three months ended 31 March 2025, down 11% from US$437mn in the fourth quarter of 2024, reflecting seasonal and market challenges.
The US$46mn revenue decrease was driven by reduced activity in the North and Latin America (NLA), Europe and Sub-Saharan Africa (ESSA), and Asia Pacific (APAC) segments, though modestly offset by higher activity in the Middle East and North Africa (MENA) segment.
Consistent with historical trends, the winter season in the Northern Hemisphere and budget cycles of national oil company clients negatively impacted revenue and profitability.
“While 2025 is expected to be a transition year for the energy services industry, the outlook for oil and gas investment and Expro remains quite compelling for the rest of the decade, so we are cautious about the near-term and more bullish over the medium- to long-term,” said Michael Jardon, CEO.
“That said, we will size our support structure, capital expenditures and other investments accordingly, so cost and capital discipline will be key themes at Expro until we have better clarity around the direction of international and offshore markets, and the timing of deepwater projects that we expected to be sanctioned in the second half of 2025 and into 2026.”
Expro showcased its commitment to advanced technology with notable deployments in Q1. The company successfully introduced its CENTRI-FI™ consolidated control console in Indonesia, enabling fully integrated tubular running services (TRS) operations from a single tablet, reducing personnel presence on the rig floor.
In the APAC region, Expro secured significant contracts, including a three-year deal worth over US$15mn to provide combined e-line cased hole and slickline services across 315 wells.
Additionally, a two-year contract valued at over US$8mn was signed in Brunei to deliver well metering services, leveraging advanced solutions like QPulseTM, Sonar Meter, and Multiphase Flow Meters.
This agreement, which began in February 2025, strengthens Expro’s role in optimising client production through precise well flow measurement.
However, APAC revenue fell 19% to $51 million from US$62mn in Q4 2024, driven by reduced subsea well access, well flow management, and well construction activity in Australia, as well as lower well intervention and integrity work in Brunei and Malaysia.
Segment EBITDA for APAC was US$11mn, or 21% of revenues, down from US$15mn, or 25% of revenues, in the prior quarter, due to lower activity and an unfavourable activity mix.
Recoverable barrels of oil from a well in the Bourdon prospect in the Dussafu Licence offshore Gabon have successfully surpassed millions following drilling
The second sidetrack DBM-1 ST2 well that has been drilled by the Norve jack-up rig for BW Energy has revealed 56 million barrels oil estimates in place. Of these, approximately 25 million barrels are considered recoverable.
Confirming the substantial oil discovery with good reservoir and fluid quality, Carl K Arnet, CEO of BW Energy, said, “The appraisal well confirms the potential for establishing a new development cluster with a production facility following the MaBoMo blueprint. We expect at least four producing wells.”
“We continue to successfully expand the Dussafu reserve base which, together with multiple additional prospects yet to be drilled, will support long-term production and value-creation in Gabon.”
Initial data shows that oil from Bourdon field has the lowest viscosity of the Dussafu discoveries measuring an average of 3.5 centipoise (cp), compared to 5 cp and 7 cp for the Hibiscus / Tortue and Ruche fields, respectively.
Evaluation of logging data and formation pressure measurements confirm approximately 11.2 metres of pay in an overall hydrocarbon column of 35.2 metres in the Gamba formation, drilled to a depth of 4,731 metres.
Bourdon is located approximately 15 kilometres west of FPSO BW Adolo and 7.5 kilometres southeast of the MaBoMo facility. The discovery will enable the Company to book additional reserves not included in its 2024 Statement of Reserves.
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