bluuebunny/crossref_metadata_2025_split huggingface dataset:
Dual Approach in Autonomous Directional Drilling: Innovations with Drillbotics 1.5 Inch Automated RSS and Virtual Rig Platforms
Authors: Soilemezidis C. , Mensah J. S. , Hollstein W. , Al Maasarani K. , Alkhawaja A. , Jamali F. , Dörfler G. , Hölzner N. , Jarbouh K. A. , Ustaoglu D. , Alukkal A. T. , Gudhane L. A. Y. , Jaeger P. , Feldmann E. , Carvajal C. A. P. , Yin A. O. , Sinkuu L. , Quayson J. , Amoah F. B. , Yahaya H. S. , Owusu K. A. , Dongoyo C. K. N. , Owusu A. , Amorin R. , Florence F. 
Published: February 2025

Abstract
SPE’s Drilling Systems Automation Technical Section (DSATS) sponsors the Drillbotics® autonomous drilling contest to promote advanced learning at participating universities. Two groups worked separately to drill a directional well hands-free and to connect to a well model to detect/close in a kick. This paper consolidates the efforts of both teams. Team A, the directional drilling team from the University of Mines and Technology (UMaT) in Ghana, developed a virtual model that replicated full-scale directional drilling operations, facilitating the development and testing of innovative control schemes and automation strategies. Leveraging state-of-the-art drilling software, real-time data analytics, and advanced control systems, the project demonstrated the potential of automated drilling technologies across both the planning and execution phases of drilling projects. Team B, from Technical University Clausthal (TUC) in Germany, designed and built a mini-rig that included a working scaled version of a rotary steerable system (RSS) tool to steer a wellbore through a block of sandstone to reach two non-planer targets. The work incorporates machine learning techniques to evaluate downhole sensor data and improve steering signal input. The modular design of the second-generation surface actuation system offers a more compact and efficient solution than its predecessor. The control architecture and network protocols are analyzed, demonstrating network delays of under 2 msec using a refined second-generation translator setup. The achievements of both teams are important to the future of drilling automation, as their approaches could be used to verify and validate third-party app’s communications prior to field release on full-scale rigs.
Remote Operation Support Based on Wearable Augmented Reality: Challenges and Field Deployment
Authors: AlRawi Layth Nabeel , Wang Lei , Socha Troy 
Published: February 2025

Abstract
In response to the evolving demands within the oil and gas (O&G) industry, this paper examines the integration of augmented reality (AR) headsets in remote operation support, focusing specifically on the challenges encountered, field deployment strategies, and considerations for global scalability and ongoing technology development. Four case studies—remote equipment surveys and troubleshooting, tubular thread inspection, field auditing, and rig site operations—are presented to demonstrate how these technologies can enable feasible solutions for remote support and collaboration, which transform traditional operational paradigms. By leveraging AR and related remote technologies, operational efficiency, safety, and cost-effectiveness are enhanced. However, the implementation of AR in harsh and remote environments introduces unique challenges. Key obstacles, including environmental conditions, connectivity limitations, data security, ergonomic constraints, and user adoption barriers, are highlighted and addressed through various mitigation strategies. For example, ruggedized and explosive atmospheres (ATEX)--compliant AR devices were deployed to withstand tough environmental conditions at drilling rigs. To manage connectivity issues in remote locations, private networks, and encryption protocols were implemented to ensure secure, stable communication channels necessary for real-time support. Comprehensive user training programs were introduced to facilitate smooth adoption and to deliver practical benefits to users. In addition to addressing these challenges, the impact of global deployment strategies and continuous technology development on maximizing the effectiveness of AR in the O&G industry is outlined. Significant operational improvements are indicated by the findings from these case studies, including a reduction in travel-related expenses and carbon emissions, enhanced accuracy in remote inspections, improved safety protocols, and decreased maintenance costs. These results underscore the transformative potential of AR when thoughtfully implemented with robust support systems, highlighting its ability to drive productivity and sustainability in O&G operations globally.
Our findings suggest that AR, paired with comprehensive challenge mitigation strategies, offers a valuable model for future applications across the industry. With continued advancements in wearable technology, remote support can further evolve to meet the industry’s demands for operational efficiency, safety, and environmental sustainability.
Qualification of Two-Part Granite-Based Geopolymers for Field Testing
Authors: Khalifeh M. , Kamali M. , Taheri A. 
Published: February 2025

Abstract
A two-part granite-based geopolymer alternative to ordinary Portland cement (OPC) was designed and tested, progressing from laboratory scale to yard scale. The mix design was proposed and evaluated based on API laboratory standards. Further, the hydraulic sealing performance was assessed using a 5-inch tubular in the lab. The recipe was scaled up to mix 450 liters of geopolymer slurry, intended to fill an 8-meter, 9 5/8-inch pipe. During the yard-scale mixing, samples were taken periodically, and the properties were compared with lab-scale data. The geopolymer mixing process met expectations for field application. Additionally, the results from rheology measurements and strength development fell within the range of lab data. Hydraulic sealability tests, both in the lab and in yard trials, depicted that the granite-based geopolymer can provide hydraulic sealability up to 20 bar of differential pressure across the testing pipe.
Assessing a Novel Glass-Based Fluid for Annular Barrier Remediation in Cemented Well Sections
Authors: Taheri Amir , Wolterbeek Tim , Olsen Max , Hatlebakk Ragni , Gardner Dave , Kragset Steinar 
Published: February 2025

Abstract
This study investigates a novel glass-based fluid for sealing microannuli in cemented well sections, aiming to enhance well integrity. The research focuses on assessing the material's sealing efficiency, permeability changes before and after remediation, and performance under pressure and drying conditions. Tests were performed on a vertically-oriented, 50 cm-long cemented annulus section, constructed using 7-inch inside 9-⅝ inch diameter casing pipe. After inducing a microannulus, baseline permeability was measured using gas and water at 80°C. Subsequently, glass-based fluid was injected using a modified hesitation squeeze method. Post-remediation tests showed a significant reduction in water permeability, from 4.8 mD to 10 µd, demonstrating successful sealing. Durability was further evaluated through pressure loading, drying, and self-sealing tests, confirming the material's effectiveness under various conditions.
The study revealed that the fluid's sealing properties and water-like rheology enable it to address microannuli where traditional squeeze cementing operations struggle, particularly in low-injectivity scenarios. Although some challenges remain, such as performance in larger defects and long-term durability, the findings indicate that glass-based fluids have significant potential for sealing defects in cement. The study also recommends further research to optimize operational procedures for field application of the glass-based fluid in well environments.
Quantifying the Impact of Cuttings and Fluid Properties on Friction Coefficient in Torque & Drag Analysis
Authors: Baldino S. , Ozbayoglu E. 
Published: February 2025

Abstract
This paper aims to enhance the accuracy of torque and drag (T&D) predictions by quantitatively analyzing the impact of cuttings bed and fluid properties on the friction coefficient (FC). The study focuses on directional and horizontal drilling operations where these factors significantly influence drilling performance. A large-scale testing facility was employed to investigate the effects of cuttings bed height and fluid properties on T&D. Torque measurements were taken under various RPMs, at on and off bottom conditions, with different water-based fluids and cuttings concentrations. By varying those conditions, the study measured the resulting torque and used these data to accurately determine the friction coefficient. An LSTM machine learning model was also utilized to predict and detect downhole anomalies in real-time, providing a surface-torque based data-driven tool able to recognize excessive friction in hole and thus estimate the stuck pipe risk during drilling operations. For unweighted water-based fluids, friction coefficients were quantified as 0.31 for no cuttings, 0.45 for low/medium cuttings bed, and 0.52 for high cuttings bed. In the absence of cuttings, polymers-based fluids showed lower torque due to high lubricity (lowest FC of 0.28), while weighted fluids were affected by barite's abrasiveness leading to the highest average FC of 0.34. Additionally, the study observed that the presence of cuttings disrupted the lubricating effect of polymers, leading to a friction coefficient of 0.48, approaching the one observed for water and high cuttings bed. Due to abrasiveness, weighted fluids peaked at 0.55. Trained, tested and validated with the collected experimental data, the LSTM model accurately predicted surface torque under varying RPM and weight on bit conditions, effectively detecting anomalies caused by poor hole-cleaning. These findings offer a comprehensive quantification of the impact of cuttings and fluid properties on the friction coefficient and introduce a surface-torque based real-time tool for stuck-pipe risk evaluation. This can lead to better management of drilling operations and reduce risks associated with poor hole-cleaning and high friction. This study presents a systematic effort to quantify the effects of cuttings and fluid properties on friction coefficients under controlled conditions and on a large-scale facility. The integration of machine learning for real-time anomaly detection and the detailed quantification of FCs offers enhanced predictive tools and valuable insights for improved T&D analysis. These contributions can benefit well engineers by providing a more accurate and reliable basis for both the design and operational drilling phases.
A Study of Instabilities Observed When Heave Compensating Deepsea Risers
Authors: Kyllingstad A. 
Published: February 2025

Summary
This paper discusses an instability phenomenon sometimes observed on drillships when latching or unlatching a long riser to the well head while the drawworks is operating in the active heave compensation (AHC) mode. The paper starts with presenting field data clearly showing an incident of instability. Next, it focuses on the physical causes or conditions for instabilities to occur. The root cause is identified to be an inherent and poorly dampened bending mode of the entire drillship. This mode has a natural frequency equal to the vibration frequency observed during the instability event. Two additional causes are also discussed in some details: the complex dynamics of the riser and the dynamics of the drawworks and its control system when run in the AHC mode. The dynamics of all 3 systems are coupled to give an analytic formula for the decay rate of the ship vibration mode. This formula is used for predicting the conditions when the decay rate is negative, and instability can occur. The paper also includes results from an advanced simulation model.
The results from this model confirm the predictions from the analytic analysis. Finally, various proposals for solving the instability problem are briefly discussed.
A Quantitative Drilling Fluids Advisor
Authors: Whyte J. M. 
Published: February 2025

Abstract
The management of drilling fluid properties has, in most cases and continues to be a highly manual process. A combination of infrequent measurements of insufficient accuracy, fluids data not being stored as a time series, limited understanding of the interactions between critical components and low levels of mixing system automation has made the creation of a system to advise on fluid treatment a considerable challenge. Our solution is to create a fluids advisor - a system of inter-connected algorithms, which work together to give quantitative recommendations of fluid treatment and management. We achieve this by combining field data collection and analysis with an in-depth physicochemical understanding to enable automated treatment advice. This advisory system was tested successfully during the drilling of two oil-based and one water-based sections in the UK North Sea.
The advisor's self-learning framework creates a workflow that encompasses the automated detection of critical fluid treatment decisions points, calculates the exact quantities of treatments required to achieve an objective and can autonomously decide if a treatment action should be taken. In addition, the advisor automatically detects the presence of contaminants in the fluid and any operation on the rig that affects the fluid system (Fluid States). This is achieved using a hybrid data-physics model created using sequential design of experiment (DoE), combined with extensive experimental work on fluid formulation and incorporation of contaminants and low-gravity solids. This allows the determination of fluid properties resulting from any treatment made to the fluid system and to prescribe quantitative treatments to fluid engineers. A self-learning data framework enables treatment recommendations from the model to be modified during and after each operation to improve advice and predictions for future operations.
Advice provided to the offshore engineers consisted of qualitative advice on different treatment and operational decision points and quantitative recommendations on what treatments were required to achieve a particular objective. 100% of qualitative recommendations were accepted by the offshore engineers with 75% being implemented immediately. Changes to properties due to treatments were predicted accurately with a MAPE of ∼5% across an API fluids check, indicating the excellent agreement between measurements and prediction. The rig's fluids engineers used the advisor (via remote operations) to optimise treatments to the fluid system. Overall, use of the advisor used 15.4% less chemical additives than offset sections.
Our approach combines both physics and data with innovative work on clay exfoliation to enable truly accurate, quantitative fluid treatment recommendations. For the first time, the process of recommending, calculating and implementing fluid treatments is automated fully.
Gulf of Mexico Deep Open Water Drilling; A Salty Evolution
Authors: D'Ambrosio P. , Perez J. Patino , Franco C. 
Published: February 2025

Abstract
As an industry we could say that the Gulf of Mexico (GOM) salt drilling challenge has been conquered. No longer do well trajectories avoid drilling through salt, no longer salt sections are limited to be vertical only, nor is salt creep common a cause of Bottom-Hole-Assemblies (BHA) lost in hole. However, over the last decade the increased complexity on deepwater fields in the Gulf of Mexico, such as increased step-out, production platform optimization, multiple geological objectives as well as Authorization for Expenditure (AFE) optimization has led to more challenging conditions for planning and executing open water work; including drilling longer riserless salt sections with more aggressive directional work, avoiding collision risks and Water-Based Mud (WBM) volume constraints due to limited volume capability despite the use of 6th and 7th generation dual activity drilling rigs. Salt drilling challenges in ultra-large diameter open water GOM continue to exist, they have evolved.
Torsional instability that leads to high levels of shocks & vibrations and over-torqued connections is the most common open water salt drilling challenge. Someone could say that this challenge lightly affects the instantaneous salt drilling performance as we keep drilling faster. However, it highly affects the overall well construction performance. Costly BHA damage equipment as well as excessive Non-Productive-Time (NPT) and Invisible-Loss-Time (ILT) time laying down BHA components that present Over-Torqued Connections (OVTC) not only affects well construction times but it's also a safety concern. OVTC requires keeping personnel exposed to red zones for extended periods of time until such connections are broken down or removed unbroken from the rig floor, causing also challenges while backloading and transporting these components.
This paper will concentrate on the drilling efficiency of the ultra-large diameter (24" – 26") riserless / open water salt drilling sections in the Gulf of Mexico. Prior SPE papers and data from 27 riserless salt drilling runs will be examined and analyzed, describing the engineering, planning and risk assessment process to optimize the BHA design on a well-by-well basis to drill safely and efficiently and to achieve the objectives established for the section. Other factors such as drilling fluid density and rig capabilities will also be discussed as an integral part of the drilling system.
Advancing Downhole Vibration Analysis Through Automated Analytics in Rotary-Steerable Applications
Authors: Brock R. J. , Wilson J. K. , Price D. B. , Prince R. B. 
Published: February 2025

Abstract
While drilling automation typically focuses on rig control systems and performance optimization, this study broadens the scope to include the evaluation of overall drilling performance and the identification of operational issues. The automation of routine analyses frees engineers from time-consuming data processing tasks, allowing them to focus their expertise on critical problem-solving and optimization opportunities. This work examines the implementation of multiple algorithms: one for identifying various downhole vibration modes, another for evaluating the directional response of a push-the-bit Rotary-Steerable System (RSS), automated connection break down analysis, and measure-while-drilling (MWD) recycling attempts analysis. These automated systems enable quicker operational responses with appropriate corrective actions.
The study begins with an assessment of data quality, emphasizing the importance of a robust cloud-based architecture for data collection, cleaning, and storage. From there, a systematic approach is taken to translate the thought process of experienced engineers into logical programmatic steps for data evaluation. The validated algorithms are deployed within cloud-based infrastructures for large-scale implementation, providing real-time access to key performance indicators and analysis results.
Detailed heat maps showing the effects of operating parameters better visualize and understand vibration trends, while automated steering interval evaluation provides insights into RSS directional performance. Connection break down analysis examines time components of drill pipe connections, and recycling analysis tracks the efficiency of MWD survey data transmission. Building these automated tools has reduced the time requirement for understanding operational data, which drastically shortens the time between identifying issues and implementing solutions.
This study introduces innovative methods for quick evaluation of drilling operations data. By ensuring consistency in identifying drilling dysfunction across teams and aiding in the professional development of less experienced engineers, these automated algorithms contribute to knowledge sharing and operational efficiency at scale.
Laboratory Setups for Evaluation of Annulus Barrier Materials
Authors: Opedal N. , Ngouamba E. , Feneuil B. , Wiggen E. , Skorpa R. , Taghipour A. 
Published: February 2025

Abstract
Barrier materials are essential to avoid uncontrolled migration of fluids in wells. In this paper we review laboratory setups developed over the past decade, focusing on the challenges and the main results. Cement systems based on Portland G cement are still widely used, but new materials are constantly developed to adapt to increasingly demanding field conditions. Laboratory tests provide a cost-effective way to develop and test new barrier materials, specifically for the annulus. Several independent groups have built down-scale setups to study annular barrier materials. Each setup aims to test the barrier material in conditions as close as possible to field conditions. We first describe and compare the different setups, focusing on their features, advantages, limitations and give examples of the results, and compare them with similar setups from the literature. The interactions between a formation, an annular material and the casing opt for many different outcomes regarding sealability. Casing eccentricity or the presence of drilling fluid at the formation wall are some examples of situations where the annular material might exhibit lower performance. However, another important parameter is the ratio between the rock/cement mechanical properties. Large ratios of Unconfined Compressive strength (UCS) and Youngs Modulus leads to higher propensity for creation of flow paths in the annulus. Flow (permeability) testing of these samples illustrate the dynamic behavior of the flow path(s) and how the micro annulus sizes are influenced by the level of the applied confinement pressure around the casing, and by the level of the pressure inside the casing. The evaluation of the flow path geometries using X-ray CT show how complex these geometries appear in "real" systems. This finding further highlights the importance of proper validation/calibration of any flow rate model or calculator. The evaluation also shows that the typical flow paths develop from existing defects. The work presented shows the development of various down-scale setups made with the objective of understanding the behavior of annular barrier materials upon effects such as temperature and pressure cyclic changes. The results illustrate the importance of continuing development of testing facilities to ensure that wells are constructed using optimized barrier materials.