OTC Recognizes 2025 Spotlight on New Technology® award winners

World Oil staff 

In late March, the Offshore Technology Conference (OTC) announced the 2025 winners of their annual Spotlight on New Technology Award. In contrast to the past two years, the number of winners this year posted a small dip, with only 10 technologies selected compared to 2024 and 2023’s 15. Of these, nine represented innovations from large companies, with one entry from the small businesses category. 

“OTC is proud to recognize these companies for their extraordinary technological contributions and advancements in the offshore energy sector,” said Alex Martinez, chairperson, OTC Board of Directors. “The technologies spotlighted this year represent the brilliance, ingenuity, and collaboration of our workforce. Together, they are leading the industry into the future and revolutionizing the field for generations to come.” 

Detailed below are figures and descriptions for each of the winning technologies, starting with the winners from larger companies and followed by the singular small business category winner. 

NEW TECHNOLOGY WINNERS: LARGE COMPANIES 

Proactive ESP management 

Fig. 1. Baker Hughes Leucipa ESP optimizer, a module of the Leucipa™ automated field production solution. Source: Baker Hughes.

A module of Baker Hughes’ Leucipa™ automated field production solution (Fig. 1), the Leucipa ESP Optimizer is setting a new standard for the intelligent, proactive management of ESPs—a critical component of artificial-lift systems. The solution analyzes and optimizes electric submersible pump (ESP) and well performance, detects and mitigates critical conditions and accurately predicts remaining pump run-life, all without the need for costly infrastructure investments. 

This groundbreaking software module’s advanced ESP performance analysis can: 

• Accurately identify critical conditions and low-efficiency ESP operations  
• Deliver specific, field-proven recommendations that can be actioned remotely, to improve optimize production 
• Incorporate full-field constraints that help optimize power consumption and prevent water production increases 

The Leucipa ESP Optimizer is designed to enable oil and gas operators to make data-driven decisions with confidence. Its advanced analytics are founded on high-quality, structured data, in the form of a comprehensive operating history for each pump—from installation to failure. In addition, because it incorporates both AI and physics-based models, Leucipa ESP Optimizer can deliver more accurate predictions than other solutions. 

The Leucipa ESP Optimizer is an agnostic tool, so regardless of the pump supplier, operators receive the real-time information required to remotely optimize full-field production and increase ultimate recovery. By detecting failure risks early, operators can proactively take remedial actions to avoid unplanned ESP downtime and production losses. Also, they can quickly and reliably act on reliable and interpretable predictions to resolve critical conditions, increase well performance and extend pump run life. 

Optimizing production from existing wells has become essential to the oil and gas industry’s efforts to meet global energy demand reliably and affordably. Through the Leucipa automated field production solution’s single pane of glass view, the Leucipa ESP Optimizer delivers the efficiencies operators need to monitor and manage hundreds of wells simultaneously, quickly detect and respond to changing conditions and zero in on areas that need attention most. 

Electric interval control 

Baker Hughes’ SureCONTROL™ (Fig 2.) Plus electric single-line, interval control valve (ICV) reduces completion deployment and response time by reducing the number of control lines and connections during completion operations, for simpler, more versatile efficient zonal control. The SureCONTROL Plus valve enables electrical remote operation and reliable, high resolution, selective control of production or injection flow rates in wells, without costly or intrusive interventions in commingled flow applications. 

Fig. 2. Baker Hughes SureCONTROL™ Plus electric intelligent completion system. Source: Baker Hughes.

Because the gauges and flow control tools are connected to the same electrical line, the system easily integrates with Baker Hughes SureSENS™ QPT ELITE downhole gauges. Reservoir production optimization and management can also be performed more easily through multiple zones (up to 10) that can be controlled downhole with just one electric line across the wellbore. 

SureCONTROL Plus is an adjustable flow regulator that integrates with SureSENS QPT ELITE downhole gauges and SureFLO flow meters, all powered from the surface through a single TEC cable. 

The SureCONTROL Plus enables adjustment of the local inflow/outflow characteristics without the use of conventional intervention methods. Multiple SureCONTROL Plus valves may be installed, providing complete zonal control and monitoring. Each SureCONTROL Plus is independently addressable, giving the operator the ability to adjust any of the zones in the well on command. Data is then sent from on-board sensors and diagnostic systems back to the surface control system over the same TEC line. 

SureCONTROL Plus offers one of the most efficient valves on the market. Its real-time production optimization through multiple bi-directional actuation system lets you make better decisions, faster. Also, with real-time system diagnostics and performance monitoring, you can quickly make proactive maintenance decisions without guesswork. 

Pipeless, gearless hydraulic drive 

The Hägglunds Fusion (Fig 3.) is a pipeless, gearless hydraulic drive system with peak plug-and-play performance. The high-torque, low-speed drive delivers high power with greater economy and sustainability. Because the Fusion drive solution is self-contained, it’s quick and easy to install and maintain, while reducing energy consumption, downtime and emissions. 

Because it completely eliminates the need for external piping. Fusion offers the convenience of similar fully electric solutions with the benefits of hydraulics! 

Surpassing demands defined by machine manufacturers and users, the Fusion was developed for maximum power density, which implies decreased installation footprint with increased power output. The manufacturing and installation times have decreased and installed weight is reduced, both of which translate into a sustainable product with less overall emissions for Hägglunds, OEMs and users. It fits anywhere a high torque solution is needed. Sample applications include offshore winch drives, wind energy, conveying systems or ocean renewable energy systems. 

Fig. 3. Bosch Rexroth Hägglunds Fusion The Power of One. Source: Bosch Rexroth.

The Fusion product family provides to the machine combinations of a maximum torque of 294 kNm, a top speed of 65 rpm and a max installed power of 75 kW, which outperforms any other pipeless hydraulic drive system. 

The Fusion is designed for the environment and is able to use environmentally friendly fluids (ISO15380) or fire-resistant fluids (ISO12922). The Fusion’s oil reservoir requires far less volume of oil compared to other drive solutions (14.5 gal), reducing the environmental risks from accidental leaks, even if mineral oil is used. Additionally, the system is fully enclosed so any leak will be contained. 

The Fusion’s innovative technology is essential for a sustainable energy transition, not only because it reduces the overall CO₂ emissions, but also because it reduces the required investments (CAPEX and OPEX). 

Hägglunds is a division of Bosch Rexroth Corporation. 

Diverless Tie-Ins 

The DeepOcean Diverless Tie-in Tool (Fig. 4) allows for advanced subsea equipment and engineered methodologies to be brought together, to ensure any flanged subsea system or infrastructure can be installed or disconnected, without the need for subsea diver intervention. This tool is primarily used in offshore Oil and Gas operations for the connection of subsea pipelines, risers and seabed equipment in challenging environments. The Diverless Tie-in Tool is typically deployed and operated by a remotely operated vehicle (ROV), removing the need for divers in hazardous, deepwater conditions. This significantly enhances safety, reduces operational costs and increases the speed of subsea installations. With its robust design, the DeepOcean Diverless Tie-in Tool can operate in extreme depths, making it ideal for deepwater projects, where traditional diving operations might not be feasible. Its innovative features include hydraulic systems for controlled movements, highly accurate positioning systems and fail-safe mechanisms to ensure secure tie-ins.

Fig. 4. DeepOcean Diver-Less Tie In Tool. Source: DeepOcean.

Developed in close collaboration with our partner Design Banken, the tool benefits from cutting-edge design innovations that further improve reliability and performance in subsea environments. In addition to its use in Greenfield installations, the tool is also valuable for subsea repairs, maintenance and upgrades, ensuring continued operational efficiency in Brownfield operations. Overall, the Diverless Tie-in Tool by DeepOcean, enhanced through the expertise of Design Banken, represents a leap forward in subsea technology, offering a safer, more cost-effective and more efficient way of completing complex underwater tasks, making it an essential asset for modern subsea construction projects. 

Integrated ground model solutions 

To meet global energy demand and the need for diversification of energy sources, the offshore energy sector needs faster, safer and more sustainable development. Fugro’s Quantitative Integrated Ground Model (QIGM) solution (Fig. 5) directly supports this goal by reducing uncertainty and streamlining near-surface site characterization for offshore wind, CCUS and pipeline projects. 

This innovative workflow integrates high-resolution seismic data with strategic soil and rock measurements and inverts this to map geotechnical parameters and reduce subsurface uncertainty. The QIGM workflow optimizes site investigation campaigns and enhances flexibility in infrastructure planning and design. 

Here’s how QIGM delivers those results: 

Fig. 5. Fugro Quantitative Integrated Ground Model (QIGM) Solution. Source: Fugro.

• Maximizing the value of Geo-data: Advanced seismic acquisition, processing and interpretation creates a highly detailed visualization of the subsurface structural and stratigraphic setting. 
• Deeper learning from data: Machine learning identifies novel correlations between in situ and laboratory tests and acoustic or elastic impedance, to improve prediction of geotechnical parameters in areas where physical samples don’t exist. 
• Building a 3D picture: Geostatistical and voxel modeling techniques transform geodata into a comprehensive 3D map of the subsurface, allowing engineers to visualize and analyze properties across the entire site. 
• Predicting ground behavior: By integrating these techniques and leveraging extensive subject matter expertise, the resultant 3D model produces reliable predictions of numerous parameters across the project site. 

QIGMs significantly reduce site characterization timelines to directly address the need for faster, safer and more sustainable offshore energy development. A reduction in field operations, accelerated project timelines, reduced offshore risk and a lower carbon footprint all drive toward a more resilient energy future. 

Automated tubular running operations 

The McCoy Smart Tubular Running (“smarTR”) system (Fig. 6) revolutionizes casing running operations through modular compatibility, wireless control and integrated technology. The system features advanced sensors in the Casing Running Tool (CRT), Flush Mounted Spider (FMS) and Dynamic Bails that provide real-time torque, hook load, RPM, pressure and operational status data via wireless telemetry. Advanced logic in the smartHUB provides an innovative control and interlock system with redundant activation conditions, ensuring precise tool engagement and operational safety. All data is communicated to the driller in real time, enhancing situational awareness through an animated graphical user interface. 

Wireless, hands-free control via a belly pack removes personnel from hazardous red zones, reducing risks and advancing safety. An active bump plate prevents errors by confirming proper tool alignment before activation, while mechanically energized safety locks further mitigate human error. These features align with industry initiatives for hands-free operations and “clear the floor” requirements, setting new safety benchmarks. 

Fig. 6. McCoy Global Smart Tubular Running - smarTR™. Source: McCoy Global.

The system incorporates Virtual Thread Rep (VTR) technology, enabling real-time, automated control, with remote torque-turn oversight and collaboration with experts to improve decision-making and wellbore integrity. Precision engineering enhances speed and repeatability, reducing slip-to-slip times by up to 30% and increasing joints-per-hour rates. 

Tested under extreme environmental conditions and still progressing through final field trials, the smarTR system is approaching full-scale deployment. Its seamless integration with hydraulic and mechanical smartCRTs reduces non-productive time, advancing key performance metrics. smarTR improves efficiency, adaptability and safety in casing running operations. 

"We are honored to receive this prestigious award from OTC," said Dusty Sonnier, Vice President, Products and Technology of McCoy Global. "Our smarTR™ system represents a significant advancement in tubular running technology, and this recognition validates the hard work and ingenuity of our team. Being acknowledged alongside industry leaders is a testament to our dedication to driving innovation in the energy sector." 

Wind turbine connection tools 

Fig. 7. Oil States TowerLok™ Wind Tower Connector. Source: Oil States.

The Oil States TowerLok™ (Fig. 7) quickly connects wind turbine steel tubular tower sections at the base and intermediate points without conventional L-Flanges, to expedite installation, cut costs, reduce vessel requirements and remove some of the typical logistical challenges that impact delivery. 

With an L-Flange system, there can be more than 100 large heavy studs that need to be individually assembled by personnel while the tower section is lifted into position during the building of the turbine tower. Given the move to larger turbines and towers, the associated studs are becoming so heavy that they may not be able to be safely handled manually. This presents a significant limitation to the traditional bolted L-Flange. 

TowerLok presents the first commercial alternative to this challenge. It offers maximum flexibility and allows preassembly, either at the factory, quayside or on a support vessel. All “loose” items are preinstalled, allowing a hands-free landing for quickly locking in place, without needing to guide bolts and studs into holes. Compared to L-Flanges, TowerLok reduces installation time by as much as 50%, which minimizes workers’ time in the “red zone.” 

TowerLok provides a robust connection method and the potential to provide real time pre-load measurement of the connection. This allows personnel to confirm the connection remains tight during its service life, which is critical for the fatigue performance of the tower design. 

Fluid testing without human intervention 

SLB’s AutoProfiler™ (Fig. 8) is a new technology designed to elevate performance throughout the well construction cycle. This human-independent fluid testing equipment connects to intelligent software to deliver full digital transformation, changing the overall process of drilling fluid management. It delivers real-time, accurate, consistent and transparent fluid data through inline testing of rheological properties, in line with API Recommended Practice 13B, along with atmospheric and pressurized density measurements from two different sampling points. 

SLB is transforming from the traditional four to six manual tests per day to conducting one rheology test every 15 minutes (plus gel times) and conducting density monitoring within seconds, all without human intervention. The unit features remote capabilities, supports automated and customized testing of fluids entering and exiting the well and is certified to ATEX, IECEx and UKCA Zone 1 standards. Its self-cleaning crossflow filter is compatible with fluids containing LCM, and automated cleaning sequences ensure longevity and system maintenance. 

Fig. 8. SLB AutoProfiler™ automated inline fluid testing. Source: SLB.

All fluid measurements are automatically transmitted to a cloud infrastructure for real-time monitoring, evaluation and integration with digital fluid software. The Drilling Fluid Advisor software enhances decision-making by immediately highlighting deviations, calculating fluid stability risks and generating automated treatment recommendations. This empowers field engineers to take proactive and informed actions, significantly mitigating operational risks.  

AutoProfiler™ delivers up to 300% more rheological tests and over 9,000 density data points daily, equipping field engineers to respond faster, optimize treatments and improve hydraulic models for precise ECD/ESD management, hole cleaning and tripping simulations. This technology drives critical decision-making, reduces HSE risks and improves efficiency by reducing field crew requirements by up to 50% through remote operations. 

Electric Completions 

Proven yet pioneering, electric completions (Fig. 9) from SLB are transforming how operators manage production across the life of the well. This electric completion solution delivers predictive, real-time control and production intelligence, empowering confident action, improved recovery and greater efficiency from even the most complex reservoirs. 

Electric completions eliminate hydraulic systems in favor of a streamlined, electric architecture. A single electric line connects multiple interval control valves (ICVs) and a subsurface safety valve, enabling two-way digital communication and zonal control—without the need for bulky, high-pressure hydraulic infrastructure. This simplification reduces installation time, lowers capital and operational expenditures, and increases system reliability over the full well life. 

Fig. 9. SLB Electric Completions. Source: SLB.

Unlike conventional systems, electric completions enable compartmentalization and adaptive reservoir management through precise zonal actuation. Electric ICVs provide a continuous choke, allowing for real-time adjustments that respond to changing conditions. This results in faster optimization cycles, improved drawdown strategies and reduced water and unwanted gas production—while enhancing total recovery. 

Beyond performance, electric completions minimize operational complexity and emissions by reducing the energy needed for artificial lift and surface processing. The system enables fewer wells to deliver the same production volumes through maximized reservoir contact and control to improve reservoir drainage—reducing surface footprint and infrastructure demand. 

Field-proven across a variety of offshore and land environments, electric completions are accessible, scalable and flexible, bringing the power of electric solutions to everyone. With this technology, operators can move beyond the limits of conventional systems to unlock the full potential of their reservoirs, with confidence, precision and predictability. 

SMALL BUSINESS WINNERS 

Battery-powered torque 

HYTORC’s Lithium Series RX (LSRX) (Fig. 10) is a revolutionary battery-powered torque tool tailored for the offshore industry, eliminating the need for an external pump while delivering exceptional performance. This explosion-proof tool is engineered for hazardous environments, ensuring safety and reliability where other electric torque tools fail. Its sealed, corrosion-resistant housing withstands rain, salt air and harsh offshore conditions, reducing maintenance costs and extending tool life. 

Fig. 10

By operating independently of a hydraulic pump, the LSRX simplifies setup, reduces equipment requirements and improves mobility on site. This self-contained design streamlines workflows, particularly in remote or hard-to-access locations like offshore structures. 

Unlike traditional tools that are vulnerable to environmental factors, the LSRX operates with unmatched resilience. It also features advanced thermal management, with internal cooling fins, thermal grease and optimized airflow, dissipating heat efficiently to maintain consistent performance during heavy use. A locking battery mechanism eliminates spark risks and ensures safety in explosive environments. Combined with contactless electronic switching, it sets a new benchmark for operational safety and efficiency. 

By removing the pump dependency, integrating data capture (via Bluetooth or USB), and incorporating advanced features, the LSRX transforms offshore maintenance. Its robust design, efficient operation, and extended service life reduce waste and energy consumption, aligning with sustainability goals. Ready for deployment, the LSRX is a safer and more efficient tool that redefines maintenance practices in the offshore energy sector.