bluuebunny/crossref_metadata_2025_split huggingface dataset:
Recovery Control - Closing the Loop in Automated Control Systems
Authors: Auld S. , Hopwood F. , Taylor W. , Kern S. 
Published: February 2024

Abstract
Drilling process automation has been a trending topic within the technical community, most recently discussed in SPE-212565-MS (Cayeux et al. 2023). Recovery control - specifically in the case of motor stalls - is not only integral to consistently completing automation control system execution, but also building confidence for the control system users and ultimate automation benefactors. Predicting, preventing, detecting, mitigating, and recovering motor stalls through automated recovery control solves an issue affecting most operators, contributing to additional bottom-hole assembly (BHA) damage and unplanned trips.
The recovery control system was designed with six major process control interfaces, two of which occur during on-bottom drilling: drilling while rotating and drilling while sliding. Each control interface is a means by which an external system can control the rig tools in a coordinated fashion, managing what control is currently active and ensuring the driller can ultimately assume control at any given time. The recovery control is customized and preconfigured with an observation window to execute the recovery process once the stall criteria has been breached while on-bottom drilling, sliding or rotating. The result is mitigated motor stalls that are consistently managed with a configurable automation system, less BHA damage, and no motor stall related unplanned trips - displaying both time and cost value.
After two years of testing the recovery control system internally, there were no undetected stalls, no false detections, and no unplanned trips due to motor stall, displaying detailed accuracy. The recovery control complements the process control, limit control, and manual control components of the automation control system to drill a stand effectively and consistently.
A complete and effective automation control system gives time back to the rig crew and allows for leadership development opportunities. The reliability gained through recovery control, faster than manual attempts, allows the driller to focus more time on safety and training the rig crew instead of monitoring differential pressure in the hopes of manually preventing a motor stall. In nearly all cases, stalls were detected faster with the automatic recovery control system compared to manual detection by the driller. Drillers cannot be expected to pay attention to the hundreds of potential drilling problems - a control system can.
There are systems claiming to identify motor stalls, but this recovery control is the only technology to date that actively detects and recovers the system from the stall.
Review of Design and Operation of the Integrated Riser Joints Used in Deepwater MPD Operations
Authors: Kulkarni Nitin , Hollman Landon , Christensen Clayton , Luis Alexa Gonzalez 
Published: February 2024

Abstract
Integrated Riser Joints (IRJ) have become a key component of deepwater Managed Pressure Drilling (MPD) operations. They enable the surface MPD system to be integrated with the riser, allowing for safe and fast installation and retrieval despite complexities.
Deepwater MPD integrated riser joints are made up of (a) a below-tension-ring rotating control device (BTR-RCD) to create a seal around the drill string during the drilling and tripping process. (b) an MPD annular packer that serves as an alternative sealing device when the rotating control device (RCD) or active control device (ACD) is not deployed or needs maintenance (c) a flow spool featuring valves and tie-in points for hoses facilitating the circulation of drilling fluids from downhole to surface equipment. (d) Choke, kill and boost line conduit to interface with the rigs riser joints. The instrumentation system installed on the IRJ enables real-time wellbore pressure monitoring and remote control of MPD flow line valves. The choke, kill boost conduits as well as mux line clamp locations facilitate a normal riser set up for surface to subsea blowout preventer (BOP) communications.
IRJs that are deployed for deepwater MPD installations represent a significant advancement over the systems used in early floating rig MPD operations. They are designed for efficient and safe deployment and are compatible with a variety of deepwater drilling systems. MPD integrated riser joints operate in a complex wellbore condition allowing efficient and effective wellbore pressure control, improving the safety of deepwater drilling operations. It enables real-time monitoring of the wellbore parameters allowing drilling supervisors and engineers to make timely adjustments to drilling parameters. This technical paper reviews key design considerations of different IRJ systems developed by the industry and used in deepwater MPD operations. The paper examines how the IRJ system has evolved over time due to the requirement for a more efficient method of deploying RCD and annular isolation devices in deepwater wells.
The authors provide an unbiased view on the recent developments of Integrated Riser Joint technology based on their experience and actual application of the system worldwide.
Lessons Learned from 150 Jet-Type Perforate, Wash and Cement Well Abandonment Operations
Authors: Hovda Lars , Mueller Dan , Phadke Amal , Nevoey Harald , Gonuguntla Praveen 
Published: February 2024

Abstract
ConocoPhillips Scandinavia (COPSAS) uses the Jet-Type Perforate-Wash-Cement (P/W/C) technique as the primary method for well abandonment in the Greater Ekofisk Area (GEA) of the North Sea. The procedure used for the abandonment process was first published in 2020 (SPE-202397-MS), as was the complementary Computational Fluid Dynamics (CFD) results used to optimize the process (SPE-202441-MS). This paper will cover the most recent learnings and the latest CFD-based design modifications made to the bottom hole assembly (BHA) with the objective to achieve the best possible abandonment plug.
Application of Gamification Techniques in Well Control Training and Competency
Authors: Jensen J. W. , Kettler T. , Ozkan F. 
Published: February 2024

Abstract
Technological advances have rapidly expanded access to competency development and learning over the last decade in various contexts outside the oil and gas industry. Expanding access to the internet using portable devices with high computing power has transformed the way people learn globally. This research collects and expands on work done recently by the International Association of Oil and Gas Producers (IOGP) to advance the use of technology in well control training and competency retention. Experiences over the past five years illustrate that the necessity of remote learning during the COVID-19 pandemic has accelerated acceptance for hybrid (combined remote and in-person) learning methodologies in the oil and gas industry. Studies into gamification over the past two decades show it has a statistically significant positive effect on cognitive, motivational and attitudinal aspects of adult learning. Synergized learning combining remote and in-person education with gamified learning systems present an opportunity to improve competency development and sustainment. Applying these learnings to develop both existing and new computer-based aspects of well control training and competency sustainment programs could improve well control competencies across the industry, thus enhancing performance in the critical process safety activities of upstream oil and gas operations. This paper summarizes two industry reports on these topics, presents detailed analytical findings of academic research into gamification, and recommends how to implement hybrid learning and gamification strategies to improve vital well control training and competency sustainment for the oil and gas workforce.
First SAGD Well Placement Using Non-Stationary Definitive Dynamic Surveys Passive Magnetic Ranging and Gyro While Drilling
Authors: ElGizawy Mahmoud , Fraser Mark , Soh Azrin , Qalhati Asaad Al , Muqarshi Moosa Al , Bahri Salim Al , Musallami Ahmed Al , Mahrooqi Hamiyar S Al , Greenwell Nicholas , Lightfoot Jonathan 
Published: February 2024

Abstract
Drilling Steam Assisted Gravity Drainage SAGD wells requires placing the lateral section of the producer parallel to the lateral section of the steam injector and within a predefined distance to maximize production. After one well is drilled and completed, the second well is drilled using advanced wellbore positioning techniques to keep the two laterals at specific distance in close proximity to each other.
Active Magnetic Ranging is frequently used for positioning of SAGD wells, whereby an electromagnetic source, such as a solenoid is run on wireline in the first well that has been drilled and distance and direction measurements are made using the MWD tool while drilling in the second well. This increases the complexity of the operation as there is requirement to convey the source tool on wireline in a horizontal well and solutions for doing this, such as a tractor or coiled tubing, add considerable expense.
Passive Magnetic Ranging PMR is a common technique to estimate the distance and direction between the two wells while drilling the second well, without any requirement to run wireline tools in the offset wellbore. However, this technique requires taking at least 10 stationary surveys every stand if not more. This conventional practice leads to significant additional rig time and often increases directional drilling complexity from hole washouts to stuck pipe events. Additionally, as the wells are drilling into each other from opposite directions, both wells have high lateral and vertical uncertainty. The close proximity of both wells and the resultant external magnetic interference makes surveying an additional challenge to the BHA design and well integrity.
This is the first worldwide application of drilling SAGD twin wells utilizing Definitive Dynamic Surveys DDS to save two hours per stand by eliminating all the rig times taking stationary surveys every stand for PMR as well as eliminating all the risk to the drilling operation due to the prolonged time of having the drill string stationary. In addition, it is the first time to run a solid-state Gyroscopic Measurement While Drilling GMWD tool to measure the accurate wellbore position of the drilling well. This had significantly reduced the uncertainty of the estimated distance and direction between the two twinned wells.
Interpretation of Along-String-Measurements and Downhole Tool Data as a Solution for Intelligent Hole Cleaning in Real-Time
Authors: Chatar Crispin , Converset Julien , Sharma Sunil 
Published: February 2024

Abstract
The drilling industry is still plagued by challenges such as losses, packoff, hole-cleaning issues, and wellbore instability. Research and development using data from multiple sources have led to the development of an intelligent hole-cleaning answer product that can be used for a wellbore risk reduction service. The service would aim to optimize the rate of penetration through better understanding of hole cleaning. This digital solution that will enhance the well construction process by optimizing hole cleaning in real time. This solution is best delivered by using a combination of data and processes from multiple sources such as along-sting measurements (ASM), surface data, and downhole tools. There are several applications for this service such as land drilling, deepwater wells, horizontal wells, multilateral wells, highly deviated wells, and extended reach drilling.
The service uses a combination of technologies previously only available as separate services. The service uses ASM sensors to optimize hole cleaning. Calibration of the cutting pressure profile with a real-time simulator using a multipoint pressure measurement along the string is provided. In addition to ASM sensors, the weight and volume of the cuttings are continuously recorded at the flow lines and compared to theoretical data. As a result, mud rheology, wiper trips, and drilling parameters can be optimized, and hole-cleaning best practices can be refined. Stuck pipe, cuttings bed buildups, and wellbore instability can be detected and mitigated against, enabling safer drilling and minimization of nonproductive time. This paper will showcase how this can be done and what visualizations can be shown. It is intended to give a peak at the solution developed.
New Techniques for Intelligent Offset Data Analysis Using Artificial Intelligence
Authors: Sheth Prasham , Chatar Crispin 
Published: February 2024

Abstract
For well construction, planning is one of the most important phases in the delivery of a well. To select the right engineering solutions, it is important to analyze offset data. It is common for engineers to search, index, and catalog offset data. Today, as it has been historically for the industry, this is mostly a manual task. In the past few years, many advances in the way data have been collected, stored, and sorted have made the data easier to access, but actually determining which data are similar enough to use as offset data is still done manually. In simple cases, engineers draw a circle around the coordinates of the well to be drilled and any data within that circle would be considered offset data. This method considers only the geospatial similarity of the wells, and it is used because of time and technology constraints. In our work, we developed a method for a data-driven solution to this problem of identifying offset data.
Data are critical for producing digital products and services. More than 2 years of research have led to the implementation of a powerful tool that allows users to search all global data to discover similar attributes for oil and gas data. In addition, the method includes the ability for users to define importance or allocate priorities to various features in the data. The mentioned advances in collecting, storing, and sorting data have been a major enabler in the evolution of this technology.
This work introduces a developed framework that aids in identifying offset data by implementing a dynamic data-driven solution to analyze and display the similarity of the offset well data in a new way.
A Platform for Data Science and Analytics at the Edge
Authors: Godumagadda A. , Groh A. , Corne E. , Kasireddy P. 
Published: February 2024

Summary
Increased digitalization in industry has brought forth a myriad of applications for data science and analytics over the past decade. As needs for advanced modeling and analytics have grown, this onshore drilling contractor embarked on a journey to centralize data acquisition, aggregation, transmission, and modeling into one platform located on-location.
This paper explains how the combination of both data exchange and modeling has allowed for the development of three novel controls applications that are combinations of traditional programming and industrial control logic. This opens doors to make advanced data science modeling, such as machine learning and online learning, available directly to existing rig control systems that do not have these capabilities.
The flexibility of this system offers significant opportunity for applying advanced analytics and data science tools at the rig site. Rig control systems are no longer limited by traditional industrial controllers but have the ability to interface with performance applications written in traditional programming languages. Applications running on our edge servers, integrated as input/output to the control systems, removes the limitations of the PLCs (programmable logic controllers) and allows us to "modernize" our control system without having to replace existing PLCs.
Novel Use of Dual-String Barrier Evaluation for an Efficient Well Sidetrack
Authors: Govil Amit , Alvenes Tina , Bose Sandip , Delabroy Laurent , Straume Martin , Zeroug Smaine , Ishberdina Gulnara 
Published: February 2024

Abstract
In oil wells, operators must prove the presence of a barrier behind multiple casings, which is expensive as they need to remove pipes and evaluate a single casing. To reduce cost and carbon emissions, we implemented a solution that involved logging through tubing to evaluate both the condition behind the tubing and the barrier behind the second pipe, while satisfying NORSOK D-10 guidelines for single-casing evaluation.
A combination of ultrasonic and sonic tools was deployed within the tubing. The ultrasonic measurements provide detailed understanding of the annular content behind/around the tubing versus depth along with position of tubing in the casing. The sonic measurements, with lower frequencies, have a greater depth of investigation and thereby evaluate the presence of any solids behind the second pipe. Extensive modeling and laboratory experiments of dual-string configurations in our research facility along with multiple sets of field data helped determination of the presence of solids using both ultrasonic and sonic measurements.
Two wells, a water injector, and an oil producer, were intervened via intervention tower in the Norwegian continental shelf (NCS). For the injector well (7-in. tubing and 9 5/8-in. casing), dual-string evaluation results were compared with the first bond log along with extended leakoff test. For the producer well (5 1/2-in. tubing and 9 5/8-in. casing), dual-string evaluation results were compared against a single-casing validation log. The validation log provides a strong degree of confidence in the dual-string evaluation results. Data from the dual-string evaluation and single-casing log will be used to generate a machine learning model for this well geometry, fluids, cement, and formation and is expected to give another high-resolution azimuthal prediction, which would allow for even higher confidence in the answers in later operations with the possible elimination of the need for a validation log.
This paper discusses an offshore case study where the technology was used in two wells in the NCS. The results and observations with dual-string logging technology will be presented in addition to the validation result after pulling the inner tubing. These dual-string log measurements were then used to streamline the sidetracking program, resulting in cost saving due to offline rig activity and minimizing contingency operation, rig time, and scope while reducing overall carbon emissions.
Revolutionizing Wellbore Intersections: Advancements in Coiled Tubing Ranging While Drilling Technology for Access-Independent Wellbore Intersects
Authors: Menard T. , Mehrotra A. , Rowcliffe N. , Moss C. , Moss F. , Rassadkin G. 
Published: February 2024

Abstract
Wellbore intersections are typically achieved using a conventional rotary drilling rig and wireline deployed magnetic ranging tools. Separate trips are made for each system in order to intersect a target wellbore. While this approach is often successful, it is time-consuming, resulting in more time spent on tripping than drilling. The extended trip times and the potential for well control vulnerabilities are issues that require attention. This paper introduces a novel solution to address these concerns.
The primary objective is to expedite wellbore intersections while improving process safety. The field-tested solution presented here involves the implementation of a coiled tubing ranging while drilling system, integrating electric current injection and sensor assembly into a single BHA with a live data connection to the surface. By eliminating separate wireline runs and reducing jointed pipe trip times, operations are significantly accelerated while dramatically improving key performance metrics. A high density of ranging data sets, averaging 3,800 samples per minute, was maintained during drilling. This method offers an efficient and safe alternative by combining multiple independent services at the wellsite into an end-to-end solution. Furthermore, the technology provides additional safety barriers that are not feasible with conventional methods.
The commercial demonstration results describe the successful deployment of the novel system, potentially yielding up to five-fold efficiency improvement compared to legacy techniques widely accepted in the industry. This new approach enables a significant advancement in wellbore intercept techniques, paving the way for enhanced operational efficiency, safety, and success in challenging wellbore environments.
Combining Machine-Learning and Physics-Based Models to Mitigate Stick-Slip in Real-Time
Authors: Yahia Hana , Romary Thomas , Gerbaud Laurent , Figluizzi Bruno , Di Meglio Florent , Menand Stephane , Mahjoub Mohamed 
Published: February 2024

AbstractDownhole vibrations can lead to significant drilling problems in unconventional wells, such as frequent tool failures that increase drilling costs. Detecting these vibrations during drilling is crucial for enhancing drilling practices. One of the most destructive types of downhole vibrations is torsional stick-slip, characterized by fluctuations in bit rotation speed between zero and several times the surface rotation speed. Typically, surface data is used for real-time diagnosis of this drilling dysfunction. In recent years, Artificial Intelligence (AI)-based detection algorithms have increasingly been proposed in the literature.However, a key drawback of AI methods is their limited applicability to wells in the same field with similar geological formations and bottom-hole assemblies (BHAs). This paper aims to address this limitation and explore solutions for generalizing these approaches. It does so by employing appropriate data normalization methods, transfer learning, and the inclusion of physics-based features. Using historical offset well data, this paper presents trained and tested machine learning models capable of predicting the stick-slip index (SSI) using sequences of surface measurements and physical features. This model can be deployed in real-time on drilling rigs to provide diagnostics and recommendations.
An Advanced Simulation Model for Drawworks and Fastline Dynamics Uncovers Risks of Spooling Errors and Other Hazards
Authors: Kyllingstad Å. , Rajic I. , Krijnen A. 
Published: February 2024

Summary
The fastline is the part of the drilling line running between the drawworks drum and first sheave of the crown block assembly. Lateral vibrations of the fastline can be severe, have a negative effect on wear rates, and can cause damage to equipment with subsequential downtime. In the worst cases, severe vibrations can cause injury or even be fatal to personal. The goal of this paper is to show how a simulation model can help to identify risk factors and remedies to minimize the likelihood of spooling errors and other hazards.
This paper presents the results from an advanced simulation model describing both the generation and decay of fastline vibrations. The model includes a dynamic drawworks model having many features, such as a multilayer Lebus drum spooling, line elasticity, sheave and line inertia, and realistic speed control response of the drawworks motors. The simulation results strongly indicate that a dominating high-risk factor for error spooling is a low fastline tension force resulting from a combination of a low hook load and dynamic effects, like a high fastline speed and a rapid speed ramp-down (high deceleration rate). Other risk factors include poor damping of the generated fastline vibrations and high fastline inclination (deviation from vertical). Even though inherent bending resistance of the wire rope is a significant damping mechanism for high-frequency vibrations, it is very weak for low-frequency vibrations generated by tension variations or by axial deflection speed reversal at layer shifts. The improved model also shows that a conventional stabilizer dampens fastline vibrations poorly. In contrast, a new type of the stabilizer, which is placed closer to the fast sheave and uses passive but tuned dampeners, shows promise. Even though it is placed at a further distance from the drum, simulations strongly indicate that it can effectively dampen low frequency fastline vibrations and thereby decrease the risk of hazards.