bluuebunny/crossref_metadata_2025_split huggingface dataset:
Towards a Practical, Generally-Applicable Condition-Based Maintenance CBM System for Mud Pumps
Authors: Yoon Dongyoung , Gul Sercan , Ashok Pradeepkumar , van Oort Eric 
Published: March 2022

Abstract
Unexpected failure of mud pumps during drilling operations can result in non-productive time (NPT) and increase well construction cost. Several prior studies and implementations of condition-based maintenance (CBM) systems for mud pumps have failed to provide a generalized solution for the variety of pump types encountered in the field, in particular by failing to detect damage early enough to mitigate NPT. Our research is aimed at improving upon this situation by developing a practical, generally-applicable CBM system for mud pumps.
In the study reported here, a laboratory test bed with a triplex mud pump was used to collect data to test a new approach to mud pump CBM. Artificial damage was introduced to the two most frequently replaced parts of the pump, i.e., the valve and piston. An accelerometer and an acoustic emission (AE) sensor were used to collect experimental data. Based on this data, an anomaly detection algorithm was constructed using a one-class support vector machine (OC-SVM) to pin-point the early onset of mud pump failure. The CBM methodology thus developed does not require prior knowledge (data) of the mud pump itself or of the failures of its components. This is key to it being more widely deployable.
The trained machine-learning algorithm in the test setup provided an accuracy greater than 90% in detecting the damaged state of the valve and piston. Only the characterization of the normal (i.e., non-damaged) state data was required to train the model. This is a very important result, because it implies that the sensors can be deployed directly onto mud pumps in the field – and additionally, that the first few hours of operation are sufficient to benchmark normal operating conditions. Also, it was observed that a multi-sensor approach improved the accuracy of detection of both the valve and piston damage. The system is able to detect early-stage damage by combining the cumulative sum control chart (CUSUM) with the damage index developed in this project.
This work is the first attempt at applying semi-supervised learning for CBM of mud pumps. The approach is applicable for field use with very little or no prior damage data, and in various working conditions. Additionally, the system can be universally deployed on any triplex pump and efficiently uses the data collected in the first few hours of operation as a baseline. Consequently, the practicality and scalability of the system are high. It is expected to enable the timely maintenance of critical rig equipment before catastrophic damage, failure and associated downtime occurs. The system has been deemed promising enough to be field-trialed, and is currently being trialed on rigs in North America.
How Deep Learning can Provide Consistent Improvement on ROP Through Different Drilling Environments
Authors: Junca Rivera Diego Alberto , Bohorquez Gutierrez Julian Ricardo , Dontsova Evgeniya , Estrada Giraldo John , Martinez Ferreira Jesus , Webb Jerry 
Published: March 2022

Abstract
Using multidimensional analysis of historical drilling parameters combined with deep learning (DL) techniques, consistent ROP improvement in different drilling environments can be achieved. This discussion is focused on how offset well data can be properly analyzed and modeled to generate valuable outputs that improve not only drilling performance but also sustainability across the entire upstream.
The workflow starts by history-matching comparable wells based on different variables such as well shape, hole size, wellbore design, downhole tools, etc. This first step is heavily based on the collaborative effect between subject matter experts working closely with data scientists to ensure only the right variables that are known to effect ROP are used and that a stable and scalable model can be aheived for different drilling environments. The process then moves to the data scientists where using multilayer perceptron models and random forest techniques allow determination of the ranking of features that affect ROP the most. The top tier features are then used to train a machine learning (ML) model to determine the average threshold of historic performance. Once the threshold is known, ML is again used to determine the optimal combination of drilling parameters that yield above-average ROP performance. This process is then repeated for each formation type and hole size. The performance range of the historical offset well data is then reviewed to determine the recommended threshold and fl score to output the highest modeling performance and the output parameter recommendations are then uploaded on a dashboard for real time guidance.
A Framework to Capture the Relationships in Drilling Data and the Propagation of Uncertainty
Authors: Cayeux Eric , Damski Carlos , Macpherson John , Laing Moray , Annaiyappa Pradeep , Harbidge Philip , Edwards Michael , Carney Jonathan 
Published: March 2022

Abstract
Drilling oil and gas wells is a complex process involving many disciplines and stakeholders. This process occurs in a context where some pieces of information are unknown, or are often incomplete, erroneous or at least uncertain. Yet, during drilling engineering and construction of a well, drilling data quality and uncertainty are barely addressed in an auditable and scientific way. Currently, there are few or no placeholders in engineering and operational databases to document uncertainty and its propagation.
The SPE has formed a cross-disciplinary technical sub-committee to investigate how to describe and propagate drilling data quality and uncertainty. The sub-committee is a cooperation between the Drilling System Automation, Wellbore Positioning, and Drilling Uncertainty Prediction Technical Sections. As the topic is vast and complex, a systematic method was adopted, where multiple user stories or pain points were generated, and ranked with the most compelling user story analyzed in detail. From this approach, a series of multi-disciplinary workflow - drilling data generators - can now be captured and described in terms of data quality and propagation of uncertainty.
The paper presents details of one "user story" focused on capturing the description of the quality and uncertainty of depths. Multiple "use cases" have been extracted from this single "user story" exemplifying how multiple stakeholders and disciplines manage, communicate, and understand the notion of wellbore depth and its relative uncertainty. Current data stores have the main objective of recording the results of processes but have very limited capabilities to store how the interdisciplinary processes generated and cross-related these results. The study explores the use of semantic graphs to capture those multidisciplinary data relationships. A minimum vocabulary has been created using just a few tens of concepts that has sufficient expressiveness to describe all the extracted "use cases", showing that the semantic graph method has the potential to describe a broad range of complex drilling related processes. The study also demonstrates that use of a parallel graph, employing other notions that do not expressly refer to the processes that generated the data can capture the description of how uncertainty propagates between each of those concepts.
This paper describes the development of an initial reference implementation of semantic graph manipulation, the associated vocabulary and the description of uncertainty and quality notions and their linkage in terms of uncertainty propagation. This reference implementation will be available as open source to the industry drilling community allowing software solutions that capture and describe the generation of drilling data through multi-disciplinary workflows, and how they relate in terms of uncertainty propagation.
Unconventional Bradenhead Cementing in the Delaware Basin – Case History
Authors: Pelton Ben , Adam Derek , Granier Garrett , Turner William , Tellez Muradas Diego , Willis John 
Published: March 2022

Abstract
This Delaware Basin case history describes a bradenhead cementing method that improves zonal isolation and top of cement (TOC). Common solutions for cementing depleted formations include stage tools, low-density slurries and reverse circulation. For this bradenhead method, cement is pumped through the wellhead valves and down the annulus to a target loss zone. Field data, lab data and the engineering model support the improvement bradenhead cementing provides across depleted formations.
The depleted Brushy Canyon formation serves as an injection interval for a two-stage bradenhead cement job. This approach isolates formations below the Brushy Canyon with a conventional first stage, while achieving TOC with the second stage pumped down the annulus. Fracture gradients of the injection interval and casing shoe constrain the cement design. To achieve adequate cement placement, the design phase includes the pressure calculations required to initiate flow and injection for the bradenhead stage. Reactive spacers are utilized to prevent annulus fluid level drop in extreme cases. A benchmarked cement bond log (CBL) quantifies the results and validates this unconventional cementing method.
More than 50 two-stage bradenhead cement jobs were executed with a TOC success rate of 100% in intermediate and production hole applications. CBL data obtained after cementing the intermediate casing confirms the two-stage bradenhead as a placement method. In areas constrained by casing shoe pressures, CBL data identified potential areas of shallow injection. These data resulted in a modification of the fluids pumped. Use of these re-engineered fluids reduced injection initiation pressures and improved cement bonding across salt and anhydrite formations. Cementing costs were reduced by eliminating stage tools, annular casing packers, and low-density cement slurries. Pumping the bradenhead job offline (off the rig's critical path) reduces cost further. These features support bradenhead cementing as an effective solution for wellbore sections with a potential injection zone.
The regulatory requirement to place cement above depleted formations resulted in many innovative cementing methods. Stage tools, low-density slurries, and reverse circulation are attempts to avoid formation breakdown, but these methods increase cost and have limited reliability and integrity. Bradenhead cementing takes advantage of the depleted interval to aid in cement placement. Although counterintuitive, bradenhead cementing has proved to be a cost-effective solution that improves zonal isolation and eliminates integrity risks associated with stage tool failures.
Novel Applications of Pozzolans to Treat Wellbore prior to Cement, Casing and While Drilling to Prevent Overburden Stress Fractures
Authors: Barry James Aloysius , Esatyana Erica , El Sayed Karim Loutfy , El-Husseiny Mahmoud Ahmed 
Published: March 2022

Abstract
This study is focused on the application of novel pozzolans (superplasticizers) ahead of cement, prior to casing and while drilling to treat and prevent wellbore fracture due to overburden stresses. This study is a combination of quantitative and qualitative analysis based on laboratory and field applications of pozzolanic materials in the construction of wells.
Pozzolans have long been applied to construction materials in order to improve lifespan and compressive strength. The application of pozzolanic materials goes back over 2000 years to the construction of Roman Aqueducts, buildings and roads known for their longevity and ability to resist corrosion and stress. These materials cover a broad range of naturally occurring and man-made materials. The most common pozzolanic materials used in drilling today include Bentonite, Kaolin, and Fly Ash. Pozzolans when combined with Portland Cement have been shown to increase the compressive strength and durability dramatically. Pozzolans are currently applied globally in cementing applications for HTHP, high loss zones and more.
This paper will examine the application in the drilling phase as an applied treatment during drilling for the reinforcement of the wellbore as well as to treat induced losses. The study will review cases for use of Novel Pozzolans for drilling, pre-cement, casing and for production zones the application of Novel acid soluble pozzolans for similar purposes. These applications validate the application of these materials beyond cementing into the drilling phase and wellbore construction for reducing backside pressure, reducing days on losses, reducing sidetrack, increasing operational ECD while drilling and cementing and achieving top of cement without inducing losses due to overburden in tight ECD window environments.
Deepwater environments provide a unique environment for the application of these novel materials as they offer some of the highest overburden environments with greatest operating costs and daily operating costs. Thusly this study has shown the applications have saved operators on multiple wells and over long periods many days and millions in operating costs with proven prevention of losses in field studies where wells were compared for offset value over a period of time. Multiple operators have adopted this technology as a result and there is a long track record of use while there are few papers on the subject. The purpose of this paper is to illustrate the best practices as well as new technologies and state of the art when it comes to the development of the latest in pozzolanics for these applications.
A Comparison of Automated and Advisory Generator Management Systems
Authors: Snijder van Wissenkerke Marcel , LaCroix Adam 
Published: March 2022

Abstract
Drilling rigs are typically powered by a set of diesel or natural gas-fueled generators which the rig personnel manually turn on or off to maintain the proper capacity to support each type of rig operations. Rig personnel have no trouble running enough generators to maintain the rig demand, but efficiently shutting down generators is an area for opportunity. Reducing the number of generators that share the overall load improves fuel efficiency and reduces emissions and maintenance costs. Rig personnel are accountable for ensuring sufficient power capacity, which often leads them to be overly cautious about shutting down generators.
Automated systems can effectively shut down generators when not needed but are challenged with bringing them back online quickly enough to avoid power limiting the rig tools. After experiencing power limitations, a driller may be inclined to turn off the automated system. The goal of this paper is to explore whether an advisory system, that provides real-time recommendations for the number of generators required to be online and on-screen breakdowns of the associated fuel and emission reductions, would promote better overall savings and a better rate of adoption than an automated system. This paper describes the results of a study comparing a fully automated generator management system with an advisory system, each of which were deployed on separate rigs. Specifically, the study compares utilization of the systems and their impact on generator run hours, power limit events, and fuel and emissions savings. Field results of both systems are compared to a model of the most optimized generator management practices to understand the full potential of the systems.
A Better Set of Eyes: Computer Vision Technology to Monitor Safety Zones and Automate Drill Pipe Tally
Authors: Watson Douglas , Morton Kenneth , Kern Sarah , Hausher Aaron 
Published: March 2022

Abstract
An indispensable item for every roughneck is the tally book, used to measure and count the drill pipe entering and exiting the wellbore. The current practice is for a crew member to measure the pipe with a pipe strap and enter the information, each time while tripping, into their tally book. This manual entry is prone to error, leading to potential mistakes in the calculated drilling depth and poorly sequenced lithologies, which in turn may contribute to an unsafe environment and drill bit damage due to inaccurate drillstring length. These mistakes often require an additional trip out of hole and increase the amount of nonproductive time. Computer vision technology has shown promise in other industries with its ability to automate similar recognition and counting tasks. A dual-use system has been developed where the same cameras for pipe counting can be used for red zone entry detection, holding the potential to enhance the overall safety of the drilling process.
A pilot application has been created serving dual applications: both counting and measuring the pipe entering the wellbore and detecting personnel movement in the red zone during pipe delivery operations. Each stage of the design process was intently developed, considering requirements for both functionalities of the system. Neural network detection algorithms, 3D localization, and drilling data signal processing all combined to interpret rig state and use the appropriate computer vision algorithms at the correct time. System practicalities such as camera placement, hardware and software robustness, and field-tested accuracy were considered. The system has been deployed for field testing in West Texas.
The system succeeded in both accurately maintaining a drill pipe count and detecting personnel in the red zone. The system is designed so that the neural network algorithms can be updated using newly collected data as new scenarios are encountered, such as new weather conditions, lighting environments, additional people on the rig floor, and other dynamic factors.
This computer vision technology is the first of its kind on a drilling rig. No other system has been developed that accomplishes not only one of the functions, but also two. Just as we have seen rapid improvements each year in driver assistance technology, the time has come to apply recent advancements in computer vision capabilities to increase the efficiency and overall safety of the rig.
Early Detection of Well Control Kick Events by Applying Data Analytics on Real Time Drilling Data
Authors: Yalamarty Sai Sharan , Singh Kriti , Kamyab Mohammadreza , Cheatham Curtis , Crkvenjakov Vladimir , Flurry Kelly 
Published: March 2022

Abstract
Kick events are some of the most life-threatening and environmentally disastrous events during drilling. Identifying potential kick events in time is valuable. Several hybrid algorithms combining physics and data analytics have been developed to help identify potential kick events from trends in real-time drilling data. These algorithms encompass all drilling operations like drilling, tripping, circulating, and making connections. The goal is to enable management by exception in real-time monitoring of wells.
Real-time drilling data acquired from the sensors on the rig and other static metadata like drill string and casing specifications are used in these hybrid algorithms. The exact data channels from the real-time data used differ based on the drilling operation the algorithm is associated with, but the most important ones are flow rate in (FLOWIN), flow out percentage (FLOWOUT), pump strokes per minute (SPM), active pit volume (PITACT), and trip tank volumes (TTKVOL). Additional data channels like lag depth and rig states are computed from these existing channels to help the algorithms. Other provisions have been made in the algorithms to automatically account for human operations like lining up with trip tanks and addition/removal of pits from active pit volume. To identify the potential kicks: data from trip tank volumes are utilized while tripping, flowback signatures calculated from PITACT are used during connections, and real-time hole displacement (HDISP) calculated from PITACT and lag depth is used while drilling. All the algorithms have been parameterized to facilitate easy tuning of thresholds. An alerting system has been implemented that triggers an alarm when the algorithms identify a potential kick event. This system can also send notifications to a real-time support team or field personnel.
Historical offset wells provided by an operator were used for testing the algorithms and fine-tuning the thresholds. We achieved a 12% false-positive rate while correctly identifying all the true well control kick events. False positives are defined as events identified by the algorithms as potential kicks but were due to some explainable operation that was accounted for in the algorithm scope. The user feedback from the alerting system was also used to improve the accuracy of the algorithms. The calculated data channels used to identify the potential kicks can also be displayed as real-time traces or in other suitable visualizations like a trip sheet or flowback fingerprints.
These algorithms were designed to be run with minimal user input. This makes them suitable for use by real-time support centers and field personnel. The ability to calculate the lag depth and incorporate that into the analysis is novel and improves the accuracy. The provisions in the algorithm to account for human operations that affect pit volumes also add to the novelty.
Implementation of MPD Systems in the Deepwater Gulf of Mexico to Drill Highly Depleted Reservoir Sections
Authors: Vaczi Kenneth , Morales Danilo , Chima Chima 
Published: March 2022

Abstract
Combined challenges of drilling deep water matured reservoir hole sections with high levels of depletion present a risk for major downhole fluid loss events, well control hazards, and the resulting high remedial cost. Reduced fracture gradient, due to depletion and near-wellbore thermal stress, combined with potential near-virgin sands results in narrow-drilling margins impacting the probability of success drilling to planned depth and meeting objectives of the well. In some can cases the narrow-drilling margins can even make these reservoirs un-drillable without alternative technologies.
Constant Bottom Hole Pressure (CBHP) variant of Managed Pressure Drilling (MPD) was identified as an enabling technology to help mitigate the risk of drilling the reservoir through the presence of highly pressure depleted sands and wellbore cooling risk mixed with virgin pressure stringers within the same interval. MPD systems were installed on two drill ships, and four (4) deepwater wells were successfully drilled through highly depleted reservoirs using MPD.
MPD enabled the downhole pressure to be reduced by using a mud weight that was hydrostatically underbalanced to the pore pressure and use surface back pressure (SBP) to maintain overbalanced to the virgin reservoir conditions during static conditions. The effect of the equivalent circulating density (ECD) due to the friction while circulating (dynamic conditions) was offset by reducing the surface back pressure and maintain a near constant bottom hole pressure at a selected depth. The MPD system also allowed the application of dynamic pore pressure verification, to reduce the uncertainty in the drilling window. At TD the drilling bottom hole assembly (BHA) was pulled while maintaining the MPD condition. Production liner was then run in MPD mode and cemented using Managed pressure cementing techniques.
This paper describes the process for the selection and implementation of MPD systems on two drill ships; it highlights the process for permitting the operations and the preparation of the rig crews to apply new developed procedures. Furthermore, the paper describes the results obtained after successfully executing the MPD drilling operations.