OTC recognizes 2026 Spotlight on New Technology® Award winners

World Oil staff 

In mid-March, the Offshore Technology Conference (OTC) announced the winners of their 2026 Spotlight on New Technology Award.  Outpacing previous years, 2026’s lineup featured 17 technologies, compared with 2025’s 10 winners.  This year, there was a focus on technologies aimed at integrating A.I. capabilities into offshore technology to promote gains in safety, efficiency and sustainability. 

Fig. 1. Kantori™ autonomous well construction solution. Image: Baker Hughes.

Per OTC’s official announcement: “From autonomous well construction and advanced bit intelligence to A.I.-driven geotechnical models and next-generation subsea push systems, the lineup underscores how rapid technological progress is unlocking new possibilities for operators and service providers alike.” 

Detailed below are descriptions and figures for each of the winners, beginning with those entries by larger companies, followed by smaller companies’ entries. 

NEW TECHNOLOGY WINNERS: LARGE COMPANIES 

Kantori™ autonomous well construction solution–Baker Hughes. This technology combines artificial intelligence and physics-based models with real-time data analytics to continually optimize performance and enable automation across planning, execution and monitoring activities. This approach supports rapid decision-making with limited human intervention, reducing nonproductive time and variability during well construction operations, Fig. 1. 

“Autonomous drilling has opened new frontiers for our industry, replacing reactive operations with intelligent systems that can learn, adapt and optimize performance in real time,” said Amerino Gatti, executive vice president, Oilfield Services & Equipment at Baker Hughes. 

“This digitally driven approach, built on decades of drilling expertise and intelligent engineering, is making well construction smarter, safer and more predictable. Baker Hughes has set the standard in this field, and Kantori marks the next chapter of digital innovation in well construction.”

Fig. 2. eSEA Push. Image: Bosch Rexroth.

This technology is designed to support the entire well construction life cycle, from connectivity and data integration to well planning and performance optimization. The solution is scalable by design and adapts to customer needs, whether for a single well or across an entire field. It is also designed to work closely with another Baker Hughes technology—Corva—which provides real-time analytics and predictive intelligence for enhanced flexibility and control. 

The technology is part of Baker Hughes’ wider digital solutions suite, where it joins Leucipa™, an automated field production solution, and Cordant™, an Asset Performance Management software. Baker Hughes aims to integrate digital solutions, such as Kantori, with the company’s other proven technologies to help customers achieve greater efficiency, extend asset life and maximize returns. 

eSEA Push–Bosch Rexroth. The eSEA Push is a product family that is part of Bosch Rexroth’s larger eSEA technology portfolio of all-electric subsea solutions. The eSEA Push product family offers an all-electric, lightweight and compact solution for automation of subsea linear valves. It features a reliable fail-safe mechanism, based on the de-energize-to-trip approach, up to safety integrity level SIL 3. The design focuses on cost efficiency by reducing both CAPEX and OPEX and full functionality with a low power of 96W to 480W. With standardized interfaces, the actuators are easy to integrate and simplify retrofit projects. Covering a range of force and stroke options up to 8 in. and 745 kN, eSEA Push is versatile for various applications. The embedded digital twin provides real-time condition monitoring, enhancing system reliability, Fig. 2. 

The eSEA Portfolio of Subsea Electric Actuators operates subsea valves fully electrically, for linear or rotary movements and low or high loads. These solutions reduce CAPEX and OPEX for subsea installations through simplified design, with field-proven safety and reliable solutions replacing hydraulics and using only low power supply. 

Fig. 3. Hägglunds Thunder. Image: Bosch Rexroth Hägglunds.

The Subsea Electric Actuators of the eSEA Portfolio cover all applications for subsea systems: Torque, Spin, Push and Drive, and for all kinds of loads. This lean, all-electric technology helps to eliminate the need for hydraulic supply and control lines to provide the ideal solution to simplify and modularize subsea installations, for shorter time to market and higher reliability. 

Hägglunds Thunder–Bosch Rexroth Hägglunds. This technology is a fully electric, frequency-controlled drive solution with the proven advantages of Hägglunds drive technology. A permanent magnet PM synchronous torque motor is a type of multi-pole electric motor, capable of delivering high torque from low to megawatt power that fits well alongside that of existing Hägglunds motors, Fig. 3. 

While the specifications for Hägglunds Thunder integrate neatly within the wider Hägglunds portfolio, they create a distinct performance envelope. The Hägglunds Thunder motor range has a nominal torque of up to 200 kNm, and it provides fully variable speed from standstill. Nominal operating speed begins at 30 rpm, which is slightly higher than solutions based on the existing Hägglunds portfolio. However, the Hägglunds Thunder range opens up to 300 rpm, and it provides near-constant efficiency at any speed above nominal. 

Fig 4. MonoX™ Expandable Casing Technology. Image: CNPC USA Corporation.

“For customers who require high, or extremely high, torque at speeds close to zero, Hägglunds electrohydraulic solutions are an ideal choice,” says Uno Sundelin, project manager for Hägglunds Thunder. “But where the requirements for torque and speed are a good fit, we can use Hägglunds Thunder to supply excellent direct-drive solutions for up to 4,300 kW of power. That’s a bold new peak, even for Hägglunds.” 

Besides such efficient power, Hägglunds Thunder offers solid protection, sustaining a 200% overload for up to 60 sec. “Reliability in unpredictable applications is what customers have come to expect from Hägglunds,” says Sundelin. “They’ll find that Hägglunds Thunder sacrifices nothing in that regard.” 

MonoX™ Expandable Casing Technology—CNPC USA Corporation. This technology offers a streamlined approach to well construction by tackling some of the industry’s most persistent challenges—lost circulation, unstable formations and restrictive casing designs—without reducing wellbore diameter. Traditional casing programs often require progressively smaller strings as complications arise, limiting completion options and increasing complexity. This technology changes that equation by enabling operators to isolate problematic zones, while maintaining the original internal diameter, resulting in simpler, more flexible well architecture and improving the chances of reaching target depth, particularly in deep and high-risk wells, Fig. 4. 

At the heart of this technology is a high-performance, expandable tubular casing engineered to balance ductility with mechanical strength. The system supports up to 30% controlled expansion while retaining post-expansion tensile strength exceeding 550 MPa. Its proprietary threaded connection preserves about 90% of pipe strength and ensures gas-tight integrity. Deployment is enhanced by a dual-cone expansion tool, which improves operational reliability and safety. Together, these innovations allow for a true monobore well profile in conditions that would otherwise require telescoping casing designs. 

Fig. 5. UltraSense™ UHTHP Bit Intelligence. Image: CNPC USA Corporation.

Critically, this technology has moved beyond the conceptual stage. Classified as Technology Readiness Level 7, it has been deployed commercially in China and the Middle East, including offshore environments. Field applications range from 8-in. to 15¾-in. casing systems, including record-setting runs for ultra-large monobore expandable casing. This technology has demonstrated the potential to cut non-productive time by over 50% and reduce costs by millions per well, all while also lowering material use and environmental impact. 

UltraSense™ UHTHP Bit Intelligence–CNPC USA Corporation. In the high-stakes environment of ultra-deep drilling, understanding what happens at the exact point of rock contact is critical. This technology brings that clarity closer than ever before. By embedding high-temperature sensors, ruggedized electronics and onboard data storage directly into the drill bit, the system captures real-time measurements at the rock-bit interface—eliminating the guesswork that comes with indirect, up-hole sensing. Designed for true high-pressure, high-temperature (HPHT) conditions, this technology operates in environments reaching up to 419°F (215°C) and 30,000 psi (207 MPa). It continuously records temperature, three-axis shock and vibration up to ±500 g and rotational dynamics up to 833 rpm. These high-resolution data allow engineers to accurately detect and diagnose drilling dysfunctions, such as stick-slip, whirl, torsional vibration, and impact—issues that often lead to inefficiency, tool damage and costly downtime, Fig. 5. 

The technology has already been proven in demanding field deployments, including extended runs of 224 and 191 hrs in ultra-deep wells under severe thermal, pressure and mechanical stress. Insights gathered from these operations have been used to refine bit selection and optimize drilling parameters, delivering measurable performance improvements. By providing a direct window into downhole conditions, this technology enables more proactive and informed decision-making. The result is fewer unplanned trips, reduced vibration-related failures and improved energy efficiency per foot drilled. As the industry pushes deeper and into more challenging reservoirs, this technology represents a significant step toward smarter, safer and more efficient drilling operations. 

Fig. 6. Fugro GeoA.I. Framework. Image: Fugro.

Fugro GeoA.I. Framework–Fugro. Offshore oil and gas projects operate in data‑rich environments under compressed schedules, particularly during early site screening and shallow hazard assessment in pre‑FEED and FEED stages. These activities are critical for derisking engineering design, construction and decommissioning, yet depend on timely interpretation of complex seafloor conditions derived from high‑resolution geophysical and remote‑sensing data. As data volumes grow, interpretation has become a bottleneck between survey acquisition and confident engineering decisions, Fig. 6. 

The Fugro GeoA.I. Framework addresses this challenge by accelerating how geospatial data are interpreted and transformed into engineering‑ready insight. Developed within the Esri ArcGIS platform, the framework applies governed automation and A.I.‑assisted workflows to convert raster survey data into consistent, high‑quality vector outputs representing seafloor morphology, sediment distribution, geohazards and existing infrastructure. By reducing reliance on manual digitization, teams can move from raw survey data to decision‑ready products faster while maintaining interpretation integrity and consistency. 

Speed is achieved without sacrificing governance or accountability. All A.I.‑assisted workflows operate within a controlled framework that prioritizes data security, ethical A.I. use and transparency. Subject‑matter experts retain responsibility for quality assurance and quality control, reviewing, validating and signing off on results in a “human-in-the-loop” approach that ensures deliverables meet engineering and regulatory requirements. 

Fig. 7. GeoLok™. Image: Oil States.

Originally designed to accelerate seafloor interpretation by automating the extraction of thousands of features, this framework has expanded to support additional phases of the offshore project lifecycle. A.I.‑assisted quality control and assurance routines enable early identification of acquisition gaps or artifacts, allowing corrective guidance or infill recommendations to be issued while survey vessels remain on location. This capability is particularly valuable for short‑fuse programs or activity changeovers. 

Ultimately, earlier access to high‑confidence interpretation enables faster identification of seafloor constraints and geohazards, supporting better‑informed engineering decisions, reduced offshore exposure and improved project efficiency under increasingly tight commercial and regulatory timelines. 

GeoLok™ – Oil States. GeoLok™ is a high-temperature geothermal wellhead with an integrated tensioning system designed to improve geothermal well integrity, reduce operational costs and enhance geothermal energy production, Fig. 7.

Fig. 8. MPD Drill Ahead Tool. Image: Oil States.

With a traditional geothermal approach, placement is often inhibited by thermal profiles and retarder requirements. Such wells use reverse cementing, which is prone to void creation and relies on expensive, increased casing weights for greater wall thickness, to manage elastic collapse. This technology decreases casing requirements and employs a “cut and pull” approach that reduces material costs, heat loss and cementing voids, to lower both geothermal well downtime and operating expenses. It also rapidly detects corrosion to provide greater protection for shallow aquifers.

Whereas standard equipment typically fails above roughly 150°C, GeoLok leverages field-proven oil and gas technology to withstand extreme conditions in deep geothermal wells over 400°C. This enables Enhanced Geothermal Systems (EGS) by supporting artificial fracture creation in hot dry rock, expanding viable sites beyond limited hydrothermal zones and accessing potentially 100x more resources globally. It also allows access to supercritical geothermal environments, delivering five to ten times more energy per well via higher thermal density and efficiency, driving lower costs and applications like fossil plant repowering. 

This technology solves several current challenges in the geothermal sector. It boosts thermal energy output and overall project efficiency and provides 24/7 well health monitoring, empowering crews to initiate immediate shutdowns or interventions if needed.  It also rapidly detects corrosion, to provide greater protection for shallow aquifers. 

MPD Drill Ahead Tool–Oil States. As the first of its kind for managed pressure drilling (MPD) operations, this tool represents an important technological advance, as it allows drilling to be initiated faster, which reduces both operating expenses and the time spent installing packer assemblies. The technology—which can be retrofitted with current MPD joints—promotes faster MPD deployment by sending the tool downhole, rather than retrieving it from the drill floor. This reduction in handling activities also promotes greater safety on site, Fig. 8. 

An MPD riser joint is a special piece of drilling equipment, integrated into a marine drilling riser string, used to monitor and control downhole pressure in real time. It uses independently inflatable double packers, seated within the joint, to contain pressure. Currently, a packer assembly requires a dedicated running tool run on drill string that must be retrieved to the surface after packer deployment, forcing the drill string to be re-run downhole. This slows operations. Oil States’ Drill Ahead Tool allows the packers to be installed without the removal and re-installation of the drill string. 

Fig. 9. Retina™ at-bit imaging system. Image: SLB.

The technology contains a lower tool section attached to the pre-existing packer assembly, with six pistons and springs that push the pistons into the internal bore of the assembly. When pressure is applied, the pistons retract. The modified running tool has a notch used to lift and apply set down force during assembly installation. Using the MPD Drill Ahead Tool produces substantial time savings when deploying the MPD Joint and Packer Cassette, reducing costs. 

Retina™ at-bit imaging system–SLB. Retina™ at-bit imaging system is a groundbreaking technology that converts measurements taken at the drill bit into high-quality borehole images. For the first time, high-frequency cutter force data can be translated into detailed borehole images, Fig. 9. 

Using a recording mode system, a PDC drill bit is tailored to accommodate sensors for forces measure capture at-bit level. Retina system captures formation details—including dips, fractures, facies and textures—without interference from any type of drilling fluid. The raw data are processed to create a borehole image for formation characterization and rock properties qualification. 

Fig. 10. FIV-III™ dual-trigger formation isolation valve. Image: SLB.

The only tool that offers imaging while drilling holes larger than 9 in. (228.6 mm), the Retina system surpasses the limitations of other technologies, improving decision-making and operational efficiency. It collects vital data during the drilling process without requiring changes to drilling operations, extra runs, or additional tools in the BHA. 

FIV-III™ dual-trigger formation isolation valve–SLB. The FIV-III™ dual-trigger formation isolation valve is a Type CC, re-closable, bubble-tight barrier for well suspension. Its standard configuration incorporates two triggers for enhanced reliability and resilience; they are protected from wellbore debris within a fluid system immune to both mud and solids, Fig. 10. 

This technology features an eTrigger™ IV isolation valve, electronic remote activation device, which enables up to 12-hr reduction in opening time and can support suspension for up to 6 months. It also features hydraulic triggers, which enable longer suspension times. 

Fig. 11. CHOKUSEN. Image: TB Global Technologies Ltd.

These triggers activate a patented mechanical actuator, housed within a separate mud- and solids-immune fluid system that protects the shifting mechanism from wellbore fluids. This mechanism generates and maintains high force throughout its travel until the valve is fully open. The valve’s performance is validated beyond the requirements of API Spec 19V: 2019, 2nd edition. All these enhancements allow this technology to provide superior operational resilience, barrier integrity and suspension duration flexibility throughout the life of the well. 

CHOKUSEN–TB Global Technologies Ltd. CHOKUSEN is the integrated technology among sensing, computation, hydraulic control and mechanical that enables offshore marine loading arms to automatically connect and disconnect to vessel manifold without mechanical link between vessels, Fig. 11. 

This new, user-friendly automation technology for a marine loading arm enhances operational efficiency and safety of offshore terminals, such as Floating-LNG or Floating Storage Terminal to reduce human work and wear of components, leading to reduced OEPX. To validate this automatic operation performance, TBG built Dynamic Test Bentch (DTB) and full scale 16" Demo-MLA at factory Nagaoka Works. This facility enables CHOKUSEN MLA to perform tests with a moving dummy manifold flange simulating the real ship motions from applicable offshore conditions given by the customers. 

Fig. 12. Bunkering Boom: Emergency Release System for Offshore Ammonia Transfer. Image: TB Global Technologies Ltd.

Bunkering Boom: Emergency Release System for Offshore Ammonia Transfer–TB Global Technologies Ltd. LNG and ammonia are attracting attention as an alternative marine fuel toward decarbonization. However, the adoption of ammonia, in particular, requires safe offshore transfer operations that do not compromise operational efficiency. To solve this, TBG developed Bunkering Boom, for LNG and ammonia. This loading solution is installed on the bunkering vessel to make ship-to-ship bunkering operations faster, safer, and covering a wider range of fueled vessels than conventional methods, Fig. 12. 

For this technology, when used with ammonia, an Emergency Release System (ERS) is equipped with a special safety device (a high-speed N2 purge system), designed to minimize the volume of ammonia spillage and make sure ammonia toxicity levels are negligible—even under emergency disconnection scenarios. 

Fig. 13. eXtreamer. Image: Teledyne Marine.

eXtreamer–Teledyne Marine. This technology represents a major advancement in marine seismic streamer technology, meeting the industry’s growing demand for ultra high-resolution (UHR) data, faster project turnaround and adaptable survey systems. Developed by Teledyne Geophysical Instruments in collaboration with Geometrics, this technology is engineered for offshore applications where clarity, reliability, and operational efficiency are critical, Fig. 13. 

This technology delivers exceptional seismic data quality across high-resolution (HR), ultra-high-resolution (UHR), and ultra‑ultra-high-resolution (UUHR) surveys. Its compact, small‑diameter design supports dense channel spacing and high‑frequency acquisition, enabling precise imaging of fine subsurface details. This makes this technology particularly well-suited for site investigations, geohazard assessment, offshore infrastructure planning, and energy exploration. 

A key advantage of this technology is its ability to acquire more data in a single pass, across multiple target depths. By varying receiver spacing along the length of the streamer, operators can optimize imaging for both shallow and deeper objectives within the same survey. This capability reduces the need for multiple passes, improves efficiency, and delivers a richer, more versatile dataset. 

This technology’s robust, gel‑filled construction further enhances flexibility by allowing longer‑than‑normal UHR streamers to be towed safely without compromising mechanical integrity or data quality. This extended-aperture capability expands the range of applications that can be addressed with a single-streamer platform. 

The system supports 2D, multi‑2D, 3D and P‑Cable configurations and can be easily reconfigured, expanded or redeployed to match evolving project requirements. Combined with its proven durability and low total cost of ownership, this technology provides a future‑ready seismic platform for today’s demanding marine survey operations. 

NEW TECHNOLOGY WINNERS: SMALL BUISNESSES 

Fig. 14. i2k Connect Inc. Image: EnrgLLM™.

HYTORC – TorcSync. Although there was no official description of the winning technology available from HYTORC before this issue was published, TorcSync is potentially linked to the firm’s ongoing innovation in bolting technology. HYTORC's tools, such as the Lithium Series II, MXT+ Hydraulic Torque Wrench, and Lightning Pump, have been recognized for enhancing safety and efficiency in industrial applications. Accordingly, OTC has bestowed Spotlight awards on HYTORC products in 2019, 2021, 2022, 2024 and 2025, in addition to this year. 

i2k Connect Inc.–EnrgLLM™. This system is a domain-adapted generative A.I. model developed by i2k Connect, a Houston-based company, in collaboration with the Society of Petroleum Engineers (SPE) and Aramco.  EnRG-LLM is the only A.I. model built on SPE’s authoritative, peer-selected technical library. The EnRG-LLM makes SPE’s corpus of expert information highly accessible to energy companies via licensing from SPE, Fig. 14.  

The EnRG-LLM solution is enhanced by the i2k Connect A.I. platform that delivers fully supported applications that provide agentic A.I., chat, GIS mapping, and advanced search and filtering for petabyte scale archives of structured and unstructured information. The applications may include access to SPE’s EnRG-LLM model and technical library. i2k Connect is implementing applications for many of the largest oil and gas companies in the world. 

Fig. 15. KeyDrill Gyro While Drilling (KGWD). Image: KeyDrill Technology LLC.

Together, these solutions transform vast energy archives within E&P companies into actionable, high-stakes intelligence. They address the scale, complexity, and data intensity of modern oil and gas projects, including offshore developments. Offshore projects are among the most complex engineering undertakings in the world, involving multi-billion-dollar investments, long lifecycles, globally distributed teams, and vast volumes of technical, operational and subsurface data. As projects become more data-driven and interconnected, artificial intelligence has a crucial role in business acceleration and return on investment. 

KeyDrill Gyro While Drilling (KGWD)–KeyDrill Technology LLC. The KGWD System features a rugged, fully retrievable design that provides a revolutionary solution for downhole navigation by enabling accurate, dependable wellbore gyroscopic surveys, as well as real-time gravity and north toolface measurements during drilling. Unaffected by magnetic interference, the system delivers exceptional precision and reliability. Moreover, the KGWD system integrates seamlessly with a range of MWD modules and LWD tools, including Resistivity tool, Azimuthal Gamma Tool, KPWD tool and Rotary Steerable System (RSS), Fig. 15. 

This technology offers three versatile GWD kit options to suit diverse operational needs within the KGWD system, including the Mud Pulse GWD Kit, EM GWD Kit and Hybrid GWD Kit. These kits are designed to provide optimal performance across various drilling environments. 

MaxFusion–Oliden Technology, LLC. This technology is the latest-generation, turbine-powered, high-speed Siren MWD Tool, delivering over 15 bits per second of physical telemetry rate. Delivering the highest data density for all downhole measurements, this tool provides unprecedented actionable information for the independent players in the oil and gas industry. Real-time Logs now look like memory logs, and the accompanying benefit from enhanced data transmission is better decision-making in real time, Fig. 16. 

Fig. 16. MaxFusion. Image: Oliden Technology, LLC.

This technology can power all tools in the LWD and RSS string; it delivers power both up and down in the BHA and, therefore, can be positioned at any location in the LWD BHA. The high-power capacity allows avoiding battery use, even in most power-hungry tools that are traditionally run with a lithium battery. 

This technology also utilizes the vast array of compressed words for curves and images, available from Oliden’s award-winning LWD portfolio, which increases effective telemetry to above 100 bits per second. 

Advanced Drilling Dynamics are standard in all Oliden tools, including MaxFusion. 

The advanced turbine has been engineered to provide sufficient downhole power to the BHA across a wide flow range, while maintaining a high LCM capability and using a novel FMEA approach. In addition, key reliability improvements have been established within the system architecture, which has been confirmed via independent validation. 

Multiple telemetry modes have been implemented utilizing the high-speed Siren, and a simple but robust downlinking scheme is employed to switch between any modes desired by the user in real time.  Now, anyone, anywhere in the oil and gas industry can now fully exploit the downhole measurements of LWD Tools by utilizing this technology and its superior telemetry rates.