CAM Integrated Solutions has announced its official entry into the offshore decommissioning market, marking a significant milestone for the company as it continues to broaden its service offerings.
CAM’s new Decommissioning Division will provide clients with turnkey solutions that ensure the efficient and environmentally responsible retirement of end-of-life assets. By integrating decommissioning with its existing services, CAM is positioned to deliver great value to operators navigating end-of-life asset strategies offshore in the Gulf of Mexico.
To spearhead the new initiative, CAM has appointed Brady Barras as the Vice President of Decommissioning. With more than 31 years of experience in the offshore oil and gas industry, Barras will bring his wealth of expertise to decommissioning project through the Gulf and beyond.
Craig Pierrotti, CEO of CAM Integrated Solutions, said, “We are thrilled to be entering the decommissioning market, a natural next step in the evolution of CAM’s integrated service offering. Brady’s depth of knowledge, hands-n experience, and commitment to operational excellent make him the ideal person to lead this new endeavour. I am confident that with Brady at the helm, CAM will quickly establish itself as a trusted and forward-thinking partner in the decommissioning space.”
An upgrade to autonomous hydraulic fracturing technology, Chevron USA and Halliburton have jointly developed a new process that allows closed-loop, feedback-driven completions in Colorado
This intelligent fracturing process combines automated stage execution with subsurface feedback to optimise delivery of energy into the wellbore without relying on human intervention.
The new process ensures efficiency and consistency during fracture execution. To top that, these new technologies come with added control functionality. Backed by digital automation and real-time feedback from the subsurface, autonomous workflows adjust completion behaviour with the goal of improving asset performance.
A combination of technologies from the wellsite to the cloud is required to enable this new approach to intelligent completions. Halliburton’s ZEUS IQ intelligent fracturing platform, comprised of OCTIV auto frac and Sensori monitoring, provides the necessary closed feedback loop and control capability. Chevron’s hydraulic fracturing and subsurface knowledge is built into an algorithm to enable the advanced decision making.
“We drive innovation in the digital space,” said Shawn Stasiuk, Halliburton’s Vice President of Production Enhancement. “We built the digital environment down to the field level and enable our customers to test their best ideas.”
Chevron’s work in closed-loop automation changes the approach to hydraulic fracturing in shale and tight rock formations. Operations can now react to a localized environment through real-time adaptation rather than performance forecasting.
“At Chevron, we focus on continuously advancing asset performance safely through the innovation of our subject matter experts, new technology, and strategic collaborations. This real-time adaptive feedback loop is expected to further drive efficiencies and improve overall asset performance,” said Chevron’s Kim McHugh, Vice President of the Rockies Business Unit.
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ExxonMobil has awarded EnerMech a contract to deliver a complete flowline decommissioning package for the Hoover Diana development in the Gulf of Mexico.
The scope includes decommissioning subsea flowlines, marking EnerMech’s first major decommissioning campaign in the region. An expert team integrating multiple service lines will be deployed from EnerMech’s Energy Solutions division to complete the full scope of work, including coiled tubing, pressure pumping, chemical services, filtration, separation and pipeline gauging.
In more detail, the scope includes flushing, pigging and filling subsea pipelines to safely remove hydrocarbons and prepare for decommissioning. This involves flushing the umbilical, pipeline flushing and seawater fill operations for the subsea flowline loop, as well as nitrogen flushing via subsea vessel, coiled tubing services and sweater filling for the Northern Diana flowline.
EnerMech CEO, Charles Davison Jr., said, “The Hoover-Diana project marks our first large-scale decommissioning engagement in the Gulf of Mexico, building on the strong relationship we’ve developed with ExxonMobil in Guyana since 2018.
“Securing this new contract following a competitive tender is a testament to our deep expertise, integrated capabilities, and the trust ExxonMobil continues to place in our team. Our early engagement has allowed us to develop a tailored methodology that maximizes efficiencies, minimizes risks, and ensures a safe, cost-effective execution.”
The Hoover and Diana fields have been a landmark offshore development for 25 years. This project will utilise the once pioneering floating production deep draft caisson vessel which gained prestige for being the deepest draft drilling and production system in the world.
Integrated decommissioning solutions, late-life asset management, and engineering services tailored for deepwater wells are among the key investment opportunities in the Gulf of America decommissioning market.
That’s according to a new report from Verified Market Research, which highlights that joint ventures and strategic partnerships are on the increase, in response to high CapEx requirements given the average cost per well decommissioning of around US$1-5mn. The rise in offshore renewable energy projects also presents opportunities to repurpose infrastructure or convert platforms to artificial reefs.
However, risks include fluctuating oil prices affecting operator cash flows, particularly now with the Iran/Israel conflict sending oil prices spiralling, and an ever-changing US tariff regime impacting the oil market. Complex regulatory requirements and regulatory uncertainty, with the rolling back of some Biden-era legislation, can also pose a challenge, along with environmental liabilities. Legal challenges from improper decommissioning and long project timelines (often 12-36 months) pose further capital exposure. Due diligence on operator history, liability transfers, and local regulatory adherence is critical for financial stability and ROI predictability, the report advises.
Key trends include a shift toward sustainable decommissioning, cost optimisation strategies, and integration of robotics and ROVs (remotely operated vehicles) to enhance efficiency and safety. There is a growing focus on sustainability, spurred by both consumer pressure and regulatory requirements, with increased use of eco-friendly materials, implementation of energy-efficient processes, and introduction of waste reduction initiatives. Reflecting developments in the industry generally, the decommissioning market is embracing digital transformation, incorporating cutting-edge technologies such as AI, IoT, and blockchain, which is significantly enhancing operational efficiency and boosting innovation.
Stringent U.S. federal mandates on well abandonment and subsea asset removal are pushing operators to adopt ESG-aligned practices, the report finds. ESG frameworks now play a decisive role in decommissioning project bids and funding eligibility, with green decommissioning, carbon footprint reporting, and stakeholder transparency becoming market entry norms. Companies integrating ESG metrics into decommissioning lifecycle planning are positioned to attract sustainable capital flows and maintain a competitive edge in this evolving offshore energy transition market, the report suggests.
An oil producer from the United States employed Emerson and the company's local partner, Puffer-Sweiven, to replace existing traditional actuator systems on shutdown valves at production wellheads with two Bettis RTS electric valve actuators
Successfully pilot-tested, the solutions reduced power consumption and surge events, improved time to market (TTM) with quick implementation, and ensured data-based maintenance decisions. The FQ Series fail-safe quarter-turn actuator mounted on a ball valve, and the FL Series fail-safe linear actuator mounted on a reverse-acting gate valve. As electric actuators, these did not require air compressors, filtration and tubing.
The existing model cost the producer high maintenance charges and operational disruptions as it required addressing failures in cases of power outages or air leaks. Diaphragm wear and corrosion in the air lines raised safety issues as they needed manual intervention. Emerson's systems eliminated this step with its onboard diagnostic features to enable remote monitoring and troubleshooting, including partial valve stroke test (PVST). Equipped to achieve Safety Integrity Level 3 (SIL3), they are mechanical fail-safe to support emergency shutdown applications with the necessary response time. To deal with outage issues, the systems come with a fail-safe 24 V DC circuit, independent of the main power grid.
Capable of operating within a temperature range from -40 °F to +140 °F (-40 °C to +60 °C), it solved the problem of frozen instrument air supply lines of the traditional actuators during colder seasons.
The new systems eliminated methane emissions which were common with each stroke from the tradional actuators.
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The Department of the Interior has announced that the lead federal agency responsible for overseeing decommissioning activities within the Chumash Heritage National Marine Sanctuary will be the Bureau of Safety and Environmental Enforcement (BSEE).
The responsibility was transferred from the Department of Commerce to the Interior, underscoring the critical role BSEE plays in managing safe and environmentally sound offshore transitions.
The transfer followed extensive coordination between the National Oceanic and Atmospheric Administration, BSEE and the Bureau of Ocean Energy Management, ensuring a unified approach to decommissioning in the Sanctuary.
Acting Assistant Secretary for Land and Minerals Management, Adam Suess, said, “This is a strong example of interagency collaboration to streamline permitting and promote responsible energy development while honouring our commitment to environmental protection. By leveraging BSEE’s regulatory expertise, we can ensure that offshore decommissioning activities within the Sanctuary are conducted safely and efficiently.”
BSEE Principal Deputy Director, Kenneth Stevens, commented, “The announcement exemplifies our commitment to streamlining processes, reducing unnecessary regulatory burdens, and promoting energy production in alignment with strong environmental protections. Early coordination between NOAA and BSEE will ensure clarity and efficiency, establishing agreed-upon mitigation measures and providing a streamlined regulatory pathway for permittees.”
In 2025, the offshore oil and gas sector in the Gulf of America is undergoing a rapid transformation, as new well intervention technologies reshape how operators approach subsea production, integrity, and high-pressure challenges.
With legacy fields maturing and operational efficiency becoming a strategic priority, companies are turning to advanced systems and partnerships to optimise well performance, extend asset life, and reduce rig time.
Chevron’s Ballymore development stands out as a symbol of this shift. By leveraging a subsea tieback to the existing Blind Faith platform, the project avoids the need for new topside infrastructure while still enabling high-yield production from three wells. This infrastructure-light approach exemplifies a broader industry trend, as operators seek scalable, sustainable solutions that reduce capital expenditure while accelerating timelines. Ballymore is expected to contribute significantly toward Chevron’s target of producing 300,000 barrels of oil equivalent per day from the region by 2026.
On the other hand, Shell is deploying innovative materials in its Whale project, located around 200 miles offshore. The company has partnered with CRP Subsea to introduce crushable foam wrap (CFW) technology – engineered to collapse under specific temperature and pressure thresholds. This provides thermal expansion management and pressure relief in the annulus, addressing critical integrity challenges in deepwater completions. Set for phased delivery starting in the third quarter of 2025, the technology reflects growing emphasis on preemptive integrity control in complex environments.
Meanwhile, intervention hardware is also evolving to meet the region’s high-pressure demands. Trendsetter Engineering has successfully deployed its Trident 20K system at Beacon Offshore’s Shenandoah project. Designed for operations in ultra-high-pressure wells, the intervention system was installed from the Deepwater Atlas drillship and enabled a two-well flowback campaign without requiring the system to be recovered between wells. Its modular design and wet-mate capabilities allowed operators to save valuable rig time while maintaining safety in technically challenging conditions.
The Gulf of America is shifting toward a model where reliability, modularity, and pressure management dominate offshore engineering priorities. As Chevron retools infrastructure usage, Shell integrates intelligent thermal solutions, and Trendsetter pushes the limits of high-pressure intervention, the region is positioning itself as a proving ground for next-gen well intervention technologies. These advancements are expected to support longer well life cycles and safer operations as operators balance performance with cost control.
Houston-based subsea hardware and offshore service solutions, Trendsetter Engineering, has deployed for the first time its flagship Trident 20K Intervention System for Beacon Offshore Energy’s Shenandoah project in the Gulf of America
The deployment was initiated from the Deepwater Atlas for a two-well flowback operation at the Shenandoah site. The system was wet-hopped between wells, which not only helped to cut down operational costs but also several days of critical path rig time. The system is currently undergoing post-campaign maintenance by Trendsetter so that it is ready for further deployments.
The launch of the 20K Open Water Intervention Riser System (OWIRS) with its first deployment marks a milestone for Trendsetter.
The 20K intervention system enhances the company's fleet of rental intervention kits. It is the realisation of a groundbreaking innovation as it has been on the cards since the company's 2020 launch -- Trident 15K Intervention System. It was the result of dedicated research, development, engineering, design, assembly, and testing.
From exploration drilling through abandonment, Trendsetter Engineering offers solutions globally.
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In yet another move to roll back Biden-era legislation, The U.S. Department of the Interior (DOI) has announced it intends to revise the Bureau of Ocean Energy Management’s 2024 Risk Management and Financial Assurance for OCS Lease and Grant Obligations Rule.
The rule increased the financial assurance requirements for offshore operators to ensure they meet their decommissioning obligations and was designed to “better protect the taxpayer from potentially bearing the cost of facility decommissioning and other financial risks associated with OCS development, such as environmental remediation.”
This rule was challenged by the Republican-led states of Louisiana, Mississippi and Texas and oil and gas industry groups, who argued that it would result in "potentially existential consequences" for small and medium-sized companies, although a federal judge earlier this year rejected their bid to block the rule. According to the DOI this rule was estimated to increase financial assurance requirements for offshore oil and gas operators by US$6.9bn in additional bonding, costing businesses an additional US$665mn in premiums each year.
The Trump administration intends to develop a new rule that will supposedly cut costs and red tape and free up billions of dollars for American producers to use to explore and produce oil and gas in the Gulf of America while protecting American taxpayers against high-risk decommissioning liabilities, according to the DOI statement.
“This revision will enable our nation’s energy producers to redirect their capital toward future leasing, exploration, and production all while financially protecting the American taxpayer,” said DOI Secretary Doug Burgum. “Cutting red tape will level the playing field and allow American companies to make investments that strengthen domestic energy security and benefit the Gulf of America states and their communities.”
The Department expects to finalise the rule this year, and will welcome public comments on the proposal.
The Bureau of Ocean Energy Management will continue to require all operators on the Outer Continental Shelf to provide financial assurance for their decommissioning obligations.
In a contract with Shell Offshore, innovative solutions provider, CRP Subsea, will be supplying crushable foam wrap (CFW) for the Whale deepwater development situated 200 miles south of Houston in the Gulf of America
The contract covers one well-set to be delivered by Q3 2025, followed further by the generation of four additional well-sets over the year. Each well-set are made of 1,798 CFW quadrants, each one metre in length. Other components include installation equipment, such as adhesive (one tube per two quadrants), adhesive dispensing guns, tie wraps, and Spanset straps.
An engineered syntactic foam, CFW comprises of a thermoset resin and hollow glass microspheres (HGMS). Once installed around the inner drill casing, it is immersed in the annulus fluid. As pressure within the annulus increases, the CFW will collapse at a pre-determined pressure and temperature combination, as dictated by well conditions. This controlled collapse allows for the expansion of annulus fluid, dispersing potentially destructive pressure build-up.
Andy Smith, Head of Sales, said, "It’s fantastic that Shell has chosen us to support this exciting deepwater project. We’ve been manufacturing and deploying crushable foam wrap for decades, helping to protect wells around the world. This contract is a great validation of our team’s expertise and dedication to delivering high-quality solutions for the industry."
The CFW will be produced at the company's Skelmersdale facility, once project engineering begins shortly.
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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."
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.
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