Following a comprehensive wireline programme, acquiring core, fluid and log data for evaluation, Talos Energy has confirmed successful drilling results from the Daenerys exploration prospect located in the US Gulf of America Walker Ridge blocks 106, 107, 150, and 151.
Drilled approximately 12 days ahead of schedule and delivered around US$16mn under budget, the West Vela deepwater drillship reached a total vertical depth of 33,228, encountering oil presence in multiple high-quality, sub-salt Miocene sands.
With the discovery well currently suspended for future use, the company is now planning to take up an appraisal well to further define the discovered resource.
"We are encouraged by the results of our Daenerys discovery well, which confirms the presence of hydrocarbons and validates our geologic and geophysical models. We believe these results support Talos's pre-drill resource assumptions. We are now working closely with our partners to design an appraisal program that will further delineate this exciting discovery. We anticipate spudding the appraisal well in the second quarter of 2026," said Talos President and Chief Executive Officer, Paul Goodfellow.
Talos, as operator, will hold a 27% working interest, Shell Offshore Inc. will hold 22.5%, Red Willow will hold 22.5%, Houston Energy, L.P. will hold 10%, Cathexis will hold 9%, and HEQ II Daenerys, LLC will hold 9%.
Following the first phase of the Dubhe-1 well programme, Pantheon Resources has successfully drilled, logged and cored the Dubhe-1 pilot hole to a total measured depth of 12,833 ft, equivalent to 8,699 ft true vertical depth.
A deviated pilot hole had to be tackled to gather cores and logs to select the optimum landing zone for a subsequent lateral sidetrack in the primary SMD-B zone. The well successfully reached the planned true vertical depth and achieved all planned target reservoir penetrations -- both primary and exploration objectives.
The primary target of Dubhe-1 was the topset horizon (SMD-B), appraising the already discovered resource. Additionally, the well was designed to encounter three further exploration horizons (Prince Creek, SMD-C and the Slope Fan System), none of which have previously had any resource estimate attributed to them. Logs confirm additional prospective resource upside in these horizons.
Post analysis of the thickness and quality of the primary target topset, the company has confirmed that the SMD-B has exceeded the upside pre-drill expectations. The gross thickness of the hydrocarbon column in this interval was measured at 565 ft true vertical thickness; exceeding pre-drill expectations by 26%.
Following this, the company plans to drill, and subsequently flow test the planned sidetrack lateral in the SMD-B horizon to refine the production well type curve.
Dubhe-1 has confirmed a gross 565 ft TVT hydrocarbon bearing column in the SMD-B primary target horizon. The hydrocarbon mix between oil, NGLs and gas will be determined after flow testing.
Erich Krumanocker, chief development officer, said, "We are delighted to announce the Dubhe-1 pilot hole results as a success. The well confirms the presence and quality of the oil and gas reservoirs in the Ahpun field, exceeding our pre-drill expectations. We are now transitioning toward field development planning in support of capital efficient commercial production. The upside presented by the SMD-C and Slope Fan zones highlights the enormous potential in our portfolio."
Autonomous subsea software company, Nauticus Robotics, has announced the Aquanaut Mark 2 has set a new record for ultra-deepwater depth off the coast of Louisiana.
The flagship fully electric-operated underwater vehicle reached depths of 2,300 metres underwater, opening new opportunities for underwater monitoring.
Daniel Dehart, Nauticus’ VP of Field Operations, said, “I am pleased to report our vehicle has reached unprecedented ultra-deepwater depths without the need of a tether. Reaching this new depth is an exciting milestone, and we have obtained significant data on both Aquanaut and ToolKITT from these tests – particularly regarding acoustic communication challenges in ultra-deepwater.
“Our Autonomous Solutions team will spend the necessary time to analyse the new data and apply this information to optimise performance for our ultra-deep applications and across our portfolio.”
CEO John Gibson commented, “The more time we spend untethered in the water, the greater our operational and technical lead expands in the market. I want to thank our employees for their dedication to innovating for our customers and their offshore projects. I’m proud that our team is constantly finding solutions to strengthen our capabilities underwater and enhance revenue opportunities for projects at these depths.”
Failure to decommission offshore oil and gas infrastructure on time and in compliance with requirements poses safety, environmental, and financial risks.
Failure to maintain offshore oil structures, while leaving them idle and unused can degrade these structures and pose safety risks to employees and regulators visiting the site. Moreover, a lack of maintenance can restrict access to the platform, requiring them to undergo expensive repairs and further contributing to delays in decommissioning operations. Moreover, poorly maintained structures lack appropriate lighting which can behave as a navigational hazard by disrupting ships that are operating in the area.
Delays and noncompliance with decommissioning requirements can give birth to financial risks, particularly to the US government and taxpayers. In most cases, post-bankruptcy decommissioning liabilities in federal waters have been met by co-owners, previous owners, or new owners. However, some instances have had the government having to use taxpayer dollars to pay the costs of cleaning up after delinquent oil companies. When a current leaseholder is unwilling or unable to pay decommissioning costs, federal regulators can, under a system known as 'joint and several liability,' require any or all co-owners or previous lease-holders to pay the decommissioning costs for that infrastructure. For big oil companies with operations in the Gulf of Mexico, these 'contingent liabilities' could amount to two to six times the amount of their direct decommissioning liabilities. Oil companies often do not report these contingent liabilities on their balance sheets.
Some observers have voiced concern and doubt about the strength of federal joint and several liability regulations and the government’s ability to force previous lease-holders to pay decommissioning costs as more offshore oil and gas facilities reach the end of their productive lives.
Stagnant oil and gas infrastructures in the Gulf of Mexico can be vulnerable to deterioration and decay, thereby becoming a source of pollution. This is because detereoration and decay of these structures can lead to oil spills due to a failure of tanks and pipelines. The resulting release of corroded metal into the water can cause chronic pollution. Generally, offshore wells that are either improperly plugged or unplugged are found to become a source of pollution along with leaky or shallow-water wells or abandoned platforms that could be significant sources of greenhouse gas emissions.
While oil spills from idle or unused oil and gas infrastructure are unlikely to discharge high volumes of material, even small amounts of oil are toxic to marine organisms—from plankton to marine mammals—and can cause adverse impacts to their health or their ability to reproduce.
Moreover, deteriorated infrastructures can be prone to hurricanes and other major weather events, which have been increasing in frequency and intensity due to climate change. The Gulf of Mexico is subject to powerful hurricanes that can destroy equipment such as oil storage tanks, move subsea pipelines, or even topple entire platforms.52 Any of these events can trigger oil spills, either directly from the damaged equipment or through impacts to connecting or adjacent facilities.
The Gulf of Mexico (GOM) is a critical region for offshore oil and gas production, with operators increasingly focusing on mature fields to meet energy demands sustainably.
As new field discoveries slow, industry leaders are directing resources towards maximising the efficiency and recovery of existing assets.
According to industry insights, the GOM accounts for a significant portion of global oil production from mature fields, where advanced well intervention techniques are proving instrumental in maintaining output.
With many platforms and wells in the region reaching the latter stages of their operational lives, optimising recovery has become a cost-effective and environmentally sound approach.
Unlike new developments, interventions on mature fields leverage existing infrastructure, minimising both capital expenditure and environmental footprint.
Technological advancements are at the heart of this strategy. Companies like Baker Hughes are introducing tailored solutions such as their Mature Assets Solutions programme, designed to enhance production efficiency while addressing sustainability concerns. Light well intervention technologies are also increasingly deployed in the region, enabling cost-effective maintenance and recovery improvements.
The well intervention market in the Gulf of Mexico is projected to grow steadily as operators shift their focus from exploration to maximising output from existing fields. Industry reports indicate increased spending on well interventions, with the region becoming a hub for innovation in this domain.
Challenges remain, including ageing infrastructure and tightening regulations. However, these also present opportunities for service providers and technology innovators. By addressing these issues proactively, operators in the GOM are positioning the region as a leader in sustainable offshore production.
The focus on mature fields in the GOM reflects a broader trend in the energy sector: achieving a balance between meeting current energy needs and progressing towards a more sustainable future. This approach ensures the Gulf remains a cornerstone of global offshore production while contributing to environmental and economic goals.
Helix Energy Solutions Group will continue its work in the Gulf of Mexico this year where it will carry out well intervention services as part of a multi-year contract with Shell Offshore Inc., signed in Q3 2024.
In the coming months, and as outlined by the contract, Helix will provide an increased minimum number of days annually with the Q5000 riser-based well intervention vessel, Intervention Riser Systems (IRSs), remotely operated vehicles (ROVs), and project management and engineering services which will cover fully-integrated operations from production enhancement to P&A.
Scotty Sparks, Helix’s Executive Vice President and Chief Operating Officer, said, “We are pleased to announce that Helix has successfully executed a long-term contract with Shell, a valued customer we have safely worked with on numerous projects around the world and with whom we look forward to continuing our excellent relationship. The contract is reflective of improving market conditions and increased demand for Helix’s assets and services, as we continue executing on our strategy by providing best-in-class and global leading well intervention services.”
Leading energy provider Expro has renewed and expanded its agreement with Di Drill Survey Services, a provider of high-end HPHT logging and Gyro survey services for complex abandonment services to both the oil and gas and geothermal sectors.
The strategic partnership agreement strengthens the growing relationship between the two energy service companies who are committed to providing premium well integrity solutions to complex wellbore situations.
Patrick Hanson, Expro’s Senior Geothermal Development Manager, said, “Our ability to partner with such a respected and entrenched company such as Di Drill aligns with our geothermal growth strategy to better serve the industry in regions where we don’t have physical locations or an established well intervention footprint. Di Drill shares the same core principals of safety, quality and integrity as Expro, this partnership was an easy decision.”
Daniel McCall, President of Di Drill Survey Services, commented, “We are honoured to have the ability to continue to grow our relationship with such an esteemed service provider in the energy sector. The ability to extend and offer existing services and additional new technologies to our business partners will allow for seamless operations between multiple services from a single provider. Thank you to the Expro team for trusting us to represent your incredible technology.”
A previous agreement enabled Expro to provide its high temperature Kinley Caliper and downhole camera product lines to Di Drill to service predominantly geothermal operations in western US. The new agreement will also include Expro’s annulus intervention solution, Octopoda, with Di Drill making its gyros available for Expro’s specific call-in work. The agreement also extends joint operations into newer regions such as Oregon, Washington, New Mexico, and across the border into Mexico.
Energy services provider Expro has completed a well cement placement project for a prominent operator from the US, Gulf of Mexico, delivering an inner-string cementing on a subsea well's 22" surface casing in a water depth of approximately 2,000 m in the Mississippi Canyon area
When integrated with Expro’s other well construction technologies, the company’s innovative Cure technology range, including SeaCure, QuikCure, and CoreCure, offers a comprehensive package for ultimate cement placement and provides a complete 'head-to-shoe' solution.
Expro's Cure technologies allowed the operator to overcome ongoing offset well challenges. These included prolonged wait on cement (WOC) periods when transitioning directly from the jet string to the 22" surface casing, and tasks associated with drilling out a 22" shoetrack.
Jeremy Angelle, Expro’s Vice President of Well Construction, commented, “Our integrated cementing solution helped save approximately 18 hours of cement related drill-out, clean-out, and WOC time when compared to offset wells. By using our Cure technologies, we removed the requirement for a shoetrack to be left in the casing string, helping to avoid previously experienced cement sheath-related challenges. In addition, the QuickCure solution reduced WOC time. This latest project highlights Expro’s commitment to provide solutions that empower our clients to overcome operational challenges and achieve excellent results.”
The Cure technology range was added to Expro’s portfolio of cost-effective, innovative solutions within the company’s well construction product line as part of the Company’s acquisition of DeltaTek in February. The DeltaTek range of low-risk open water cementing solutions help increases clients’ operational efficiency, delivers rig time and cost savings, and improves the quality of cementing operations.
The global offshore well intervention market is set for a period of extended growth in light of stable oil prices forecast in the short-term, maintained oil demand in the medium- and possibly long-term, and ever-increasing environmental pressures.
Globally, spending on well intervention is on the rise with Rystad Energy predicting an increase by almost 20% in 2023 to take the total tally to US$58bn. This is just the start of a forthcoming surge with 17% of wells predicted to go through the intervention process by 2027.
North America accounts for 64% of the total wells ready for intervention by 2027, according to Rystad, giving rise to the dramatic potential of the market in the Gulf of Mexico. According to BSEE, there are approximately 1,885 active production platforms on the OCS with more than 60% older than 25 years.
This is leaving operators grappling with the need to maintain production rates while also dealing with ever-ageing infrastructure, with mounting regulatory pressure increasing the need to address decommissioning obligations. In facing this conundrum, an increasing amount of well intervention activity is highlighting the importance of this service as a means to address both sides.
As new technological innovations become more viable and the understanding around methods such as light well intervention build, the market will only advance in stature, suggesting it will finally meet the potential it has promised for so long, creating a tantalising future for the crowd of service and equipment providers offering their assistance.
Trendsetter Engineering, a provider of specialised subsea hardware and offshore service solutions from exploration drilling through to abandonment, has announced the recent completion of two deepwater well stimulation campaigns for major operators in the Gulf of Mexico.
The two campaigns resulted in the successful acid treatments of a combined six wells. The campaigns arrived on the heels of a contract agreement to deliver hydraulic intervention and technical services via the Subsea Tree Injection Manifold (STIM) for a Hydrate Remediation and Flowline Flush Project in the Gulf of Mexico.
The Trendsetter STIM offers a 15,000psi rated subsea safety system designed to provide hydraulic well access for both vertical and horizontal tree types. In addition to hydraulic well stimulation, the STIM unit has been used and is capable of supporting various other hydraulic intervention operations including hydrate remediation, bull heading of kill weight fluid and cement as well flowline flushing and testing operations for both pre and decommissioning.
Expro has secured a contract with a major operator for the first deployment of its unique single shear and seal high-debris 15K ball valve assembly.
The multi-functional single shear and seal mechanism will form part of a full subsea deepwater completion/intervention system being designed by Expro for a long-standing and valued customer for a deepwater subsea field at about 6,600 ft in the Gulf of Mexico.
The mechanism is designed to answer the customer’s requirement for a versatile, single-valve subsea solution rather than the conventional double-valve system while offering the reassurance of risk reduction through an additional safety barrier.
Graham Cheyne, Expro’s Vice President of Subsea Well Access, commented, “We are proud to offer our innovative shear and seal solution to meet the needs of this important customer in the Gulf of Mexico. Our cutting-edge technology propels the industry’s momentum towards increased automation, improving safety on the rig floor by minimising personnel and mitigating human error, while providing an additional safety barrier. It offers operators with flexibility for their operations in both in-riser and open water subsea applications.”
Expro’s high-debris single ball system, which delivers shear and post shear seal on a multitude of sizes of coiled tubing, slickline, and electrical cable, is a solution for both gas and liquid. Its versatility makes it suitable for deployment in both in-riser or open water environments.
It is NACE MR0175 compliant and qualified for sour hydrogen sulfide environments. Bi-directional sealing is available even after a pump-through. The mechanism has been qualified to API 17G standard for the performance and design of subsea well intervention equipment. Its ability to handle up to 15% debris is a significant improvement over alternative mechanisms used in this environment today.
Expro’s shear and seal valve is available in the ELSA-HP 15ksi enhanced landing string assembly. It can be configured as a single valve, a single valve with a latch mechanism, or as a conventional subsea test tree arrangement, enabling flexibility. Expro is currently integrating the shear and seal ball system into its ELSA-HD 10ksi equipment and open water offerings.
C-Innovation (C-I), an affiliate of Edison Chouest Offshore (ECO) and its family of companies, has announced the completion of its 46th well intervention in the Gulf of Mexico.
C-I, a leader in providing turnkey intervention services for the global subsea industry, also successfully completed three new riserless zone perforations, an industry first in both deepwater and high-pressure operations. The well intervention programme provides increased efficiency along with faster response times for emergent situations through the quick mobilisation and deployment of a vessel. C-I specialises in downhole operations, including production injection and integrity logging, caliper measurements, and setting water shut-off and zone bypass plugs. With more well intervention operations planned for 2023, C-I has played a pivotal role in increasing output for operators in the Gulf of Mexico.
George Wilson, Riserless Light Well Intervention Project Manager, C-I, said, “We are very proud to be a part of increasing oil production in this challenging geo-political climate. Riserless interventions on vessels offer both time and cost advantages over riser interventions. C-I’s programme offers the added benefit of dedicated dock space with advanced fluid tracking for faster between-well maintenance.”
C-I’s well intervention programme, which made its debut in 2017, has performed 31 hydraulic interventions and 15 mechanical interventions. The mechanical interventions included a total of 85 successful wireline runs, both e-line and slickline. C-I recently completed its longest mechanical intervention on board the vessel, Island Venture. With 79 days offshore, the operation included 22 e-line and slickline runs, as well as 22,205 barrels of fluid pumped into the well.
Wilson added, “C-I is a fully integrated service provider for our clients. Our turnkey solutions for well interventions alleviate the hassle of coordinating and managing the multitude of subcontractors needed to address complex jobs."
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