Drilling & Completion Tech Digest

Agentic AI-based solution expected to shorten ADNOC’s development planning from years to weeks

ADNOC and AIQ recently launched ENERGYai, a custom-built solution that combines large language model technology with “agentic” AI.

These AI agents are being trained in specific tasks across ADNOC’s value chain, which can bring a new level of autonomy and precision to critical tasks, from seismic analysis to real-time process monitoring. 

This innovation was developed by AIQ in collaboration with G42 and Microsoft and integrates open subsurface data universe (OSDU) frameworks and OpenAI models. It was trained on 80 years of ADNOC’s data over the course of a three-year development program. Testing with real-world data sets was expected to begin by the end of 2024.

ADNOC anticipates ENERGYai will accelerate by up to 75% the building of detailed geological models using very large and diverse data sets to support planning and development of large-scale CO2 storage solutions. 

In development planning, ENERGYai is expected to help ADNOC accelerate plans from 1-2 years to weeks, minimizing costs and emissions in the process. Because ENERGYai can analyze multiple scenarios in parallel – running detailed, highly advanced simulations across all variables – faster and more accurate decisions can be made. 

104 joints of TBG1 connection run in first field deployment

The TenarisHydril TBG1 connection has completed its first field deployment in Alberta, Canada. With an average running speed of 35 joints per hour, 104 joints were run with zero rejects and no breakouts.

The connection is an alternative to the API external-upset-end (EUE) tubing connection commonly used for mature fields and heavy oil production. It can be useful for operations where no metal-to-metal seal is required.

The design of the EUE connection leaves a gap between the pins, known as the J area, which is susceptible to internal erosion caused by sand and fluid production. The pin-to-pin contact in the TBG1 connection removes the J area, reducing internal erosion.

With five threads per inch, compared with eight in API EUE, the makeup process is faster, improving running speed. Additionally, its proprietary thread design withstands multiple makes and breaks, while its non-upset configuration allows for multiple thread re-cuts.

Partnership targets deployment of automation, robotics on Velesto rigs

Velesto Drilling, Petronas and NOV are embarking on an agreement to implement mechanized automation processes and integrate robotics into drilling operations.

The companies aim to establish a collaborative framework that leverages NOV’s NOVOS drilling automation system and other energy carbon optimization solutions, including robotics technology, on Velesto-operated rigs. This collaboration also focuses on optimizing drilling operation efficiency in Malaysia, reducing emissions, and achieving cost efficiency through advanced automation and digitalization technologies as key enablers.

Under the memorandum of understanding, PETRONAS will provide operational guidance on the deployment of NOVOS and robotics, while Velesto will oversee the integration and optimization of these systems on its drilling rigs. NOV will provide technical support and training for local implementation and knowledge transfer.

The collaboration intends to emphasize a strategic approach to enhancing sustainable operational efficiency and fostering local capability development in the energy sector. 

Frac pump achieves 13,000+ pumping hours before first overhaul in the Permian 

An SPM WS 335 Frac Pump recently achieved more than 13,000 pumping hours in the Permian before its first overhaul. That compares with conventional frac pumps that are commonly rebuilt at 3,000 hours and discarded at 6,000 hours. 

The WS 335 features a single-piece cast frame construction that eliminates welds, which reduces failure risk and NPT.

In the Permian project, the pump averaged 15 pumping hours per day at an average of 9,000 psi. The overhaul was performed as a routine maintenance protocol. The frame was found to be free of cracking, and the gear train and crankshaft exhibited minimal wear. The main bearings and all soft bearings were replaced before the WS 335 was returned to the field to continue pumping.

New solutions for intelligent telemetry and autonomous geosteering launched to extend drilling performance

SLB recently introduced two AI-driven innovations for drilling: a high-speed intelligent telemetry and an autonomous geosteering solution.

Stream was designed to overcome the limitations of conventional mud pulse telemetry. It combines proprietary AI algorithms with SLB’s TruLink definitive dynamic survey-while-drilling service. This provides uninterrupted, high-speed, high-fidelity real-time subsurface measurements with no data limitations, regardless of depth, even in challenging conditions.

The solution has already been deployed in 14 countries, with more than 370 runs and more than 1.5 million ft drilled. In the Middle East, Stream telemetry helped a major operator overcome difficulty in geosteering operations caused by harsh drilling conditions and poor signal quality. Using Stream, the operator was able to receive high-quality data at depths in excess of 50,000 ft — resulting in one of the longest offshore extended-reach wells ever drilled.

Separately, SLB introduced Neuro autonomous geosteering, which dynamically responds to subsurface complexities to drill more efficient, higher-performing wells, while reducing the carbon footprint of the drilling operations.

Using AI, Neuro geosteering integrates and interprets complex real-time subsurface information to autonomously guide the drill bit through the sweet spot. Geologists will not need to manually interpret data to identify a well target, update the well plan and trajectory, then communicate this to the directional driller.

“Using advanced cloud and edge AI capabilities, the system automatically selects the best route for drilling the well based on high-fidelity downhole measurements, bringing the well trajectory in line with the real-world conditions of the reservoir,” said Jesus Lamas, President, Well Construction, SLB. 

Neuro geosteering builds on SLB’s Neuro autonomous directional drilling, which drills wells to a defined well target in accordance with the well plan. Neuro geosteering takes this a step further — incorporating high-fidelity downhole measurements that ensure certainty of well placement in the best part of the reservoir.

In Ecuador, SLB deployed Neuro autonomous geosteering to drill the 2,392-ft lateral section of an onshore well for Shaya Ecuador. During this operation, SLB’s autonomous system completed 25 autonomous geosteering trajectory changes, with each interpretation and decision cycle taking only seconds. 

New survey explores industry’s digital strategies 

A recent report, undertaken between Kongsberg Digital and the Energy Council, revealed several findings around how senior leaders in the energy industry view the adoption of digital technologies:

Digital technologies were found to be predominantly applied in enhancing direct asset performance, with 50% of respondents using these tools for immediate operational improvements.

Data transformation and quality improvement command the highest budget allocation when it comes to digital investments, while investments in remote access are more conservative.

Cybersecurity and data transformation are the most sustained areas of focus, while AI and machine learning are also seeing significant engagement.

Nearly 89% of respondents support the role of digital technologies in improving energy security and affordability, but there was more uncertainty around the measurable effects on emissions reduction, with 19.4% expressing neutrality.

More than 90% of respondents support the use of digital decision-making frameworks, performance metrics and analytics to optimize the decision-making process.