bluuebunny/crossref_metadata_2025_split huggingface dataset:
Automated Procedural Compliance Drives Real Time Drilling Optimization
Authors: Kamyab Mohammadreza , Yalamarty Sai Sharan , Rogers Philip , Cheatham Curtis 
Published: February 2020

Abstract
Operators have established procedural requirements as part of their HSE, risk and cost control policies. Automating procedural compliance enables real-time operations oversight while reducing risks associated with manual processes. A novel technique was developed and implemented to automatically check rigs’ procedural compliance with an operator's guidelines and alert users in real time.
Textual procedures are initially converted into structuralized JSON (JavaScript Object Notation) format making it easier for the user to form the logics and generate a format usable for the computer. Each procedure consists of starting and ending triggers and compliance rules. As WITS data is fed to the engine, they are automatically compared against the given guidelines. Triggers are detected in WITS data using automated rig activity detection (e.g. wash up, or rotary drilling). Subsequently, compliance rules are checked and, if all criteria are met, it is detected as complied; otherwise, an alert is triggered.
The following procedures have been developed and deployed: zeroing of weight on bit and mud motor differential pressure for more accurate ROP (rate of penetration) optimization, lowering BHA (bottom hole assembly) back to bottom with reduced RPM, connection practice procedure, and capturing steady-state hook-load values for improved torque and drag monitoring. Each procedure was identified to influence future optimization efforts to a varying degree. Consider if the weight on bit is not zeroed properly it can cause incorrect driller's road-map recommendations for new wells.
The framework has been extensively tested and refined with the assistance of a Permian operator until it reached an acceptable accuracy: 95% for back-to-bottom procedure, 99% for zeroing WOB (weight on bit), and 90% for zeroing DIFF (differential pressure). Reports have been generated to display the statistics of the compliance for each rig and crew. A Permian operator, who has field tested the procedural compliance application, estimates that it will save millions of dollars per year by avoiding costly equipment damage as well as from significant time savings by standardizing a back-to-bottom procedure.
Real-time procedural compliance is a novel technique to check whether the rig personnel follow the operator's procedures. It has a flexible back-end interpreter, and each procedure is provided separately. This ensures the procedure is not attached to the original code and can be easily modified. Through the use of a real-time compliance engine, every operator can load their respective procedures and check for compliance in real-time.
Wellhead Movement Analysis with a Finite-Element Model for Well Integrity Assessment of Complex Configurations
Authors: McSpadden Albert R. , Cooper Richard G. , Trevisan Ruggero 
Published: February 2020

Abstract
Analysis of mechanical and thermal-induced wellhead growth and resultant loads is critical for tubular stress design and failure analysis of offshore platform wells. A particular need to address is the growing trend of field life extension projects for platform installations in which outer structural casings are retained. In most cases this involves installation of a new completion and often entails well conversion to new purposes different from the original design basis. Another key feature is the use of mudline suspension (MLS) systems for wells drilled in various water depths. For well integrity assessment of these and other complex configurations, wellhead movement analysis with a 1-D finite-element model (FEM) is described by which diverse configuration and analysis scenarios are accommodated in a comprehensive analysis.
The wellhead movement analysis presented uses standard FEM techniques for structural analysis with 1-dimensional linear or non-linear bar members. This is based on the familiar structural stiffness matrix. Because the wellbore system may be discretized as needed, it is straight-forward to accommodate a wide variety of well configuration options and well integrity factors. Likewise the wellhead movement model need not be limited to a single degree of freedom (DOF) at the wellhead itself but rather can and should accommodate the full complexity of the real-world configuration. Hence multiple degrees of freedom involving multiple MLS hangers or failed components are included for explicit analysis.
Due to the aging infrastructure of many mature offshore assets, the ability to economically and safely exploit remaining reserves may depend on the suitability of retained casings. Thus it is necessary to accommodate a variety of infrastructure integrity issues such as wall loss from corrosion, weakened connections, and damage to cement or grout. Another frequent design issue arises from the prevalence of MLS systems. These introduce an extra degree of freedom which makes wellhead movement analysis more complex, especially if problems arise during installation. Problems with tiebacks in a well featuring an MLS system do arise and a case study is given to demonstrate the level of flexibility required to correctly and safely assess operational parameters.
Aside from the analysis model itself, the interaction of wellhead movement and well integrity degradation on ageing and re-purposed offshore platform wells is given detailed attention. Also potential complications involved in MLS configurations are demonstrated. Building on previous work, the analysis methodology and case studies discussed in this work provide an explicit and intuitive approach to wellhead movement and loads. Certain types of wellhead load events which are not accommodated using available commercial software are modeled and analyzed.
An Evaluation of the Cement Sheath Quality of Casing Sections Recovered During a Well Abandonment Operation
Authors: Obando Palacio Guillermo , Gardner Dave , Delabroy Laurent , Govil Amit 
Published: February 2020

Abstract
Cemented casing sections were recovered from the upper part of a Norwegian North Sea production well during a permanent abandonment operation. The barrier quality of the cement sheath, which has been sandwiched between two casing strings for more than 30 years since the well was constructed, has been investigated. Measurements recorded using acoustic logs, fluid leakage testing, and core plug analysis are evaluated, and the results are presented.
Two sections were selected from those recovered during well abandonment, the deepest from approximately 260 m depth and a second from the interval covering the top of cement (TOC). The leakage properties of these sections were measured using water and nitrogen. Core plugs were recovered from the top and bottom of each section and petrophysical, chemical, and mechanical properties were measured. The casing ends were sealed with pressure-tight bulkheads enabling acoustic logging to be performed under pressure. The sections were logged at their initial condition: "dry", as delivered onshore and thereafter "wet" after attempting to saturate them with water.
Initial leakage testing with nitrogen enabled the distribution of the fluid leakage paths through the ends of each section to be visualized. The leakage path properties were observed to vary axially along each section and also for different positions around the azimuth of the outer casing. The acoustic logs were analyzed and provided a detailed map of the axial and azimuthal variations of the cement bonded to the inner casing of each well section. The variation of the log response recorded under dry and wet conditions was correlated with the leakage property variations measured along and around the casing sections. The log response was found to be consistent with the physical observations and leakage test results. The presence of microdebonding between the casing and cement and the transition to mud solids and fluid pockets above the top of the cement were readily observed.
A unique and comprehensive data set has been acquired comprising acoustic logs and laboratory measurements of water and gas leakage rates and cement properties, recorded on casing sections retrieved after more than 30 years of operational exposure downhole. The measurements enabled the cement log analysis to be compared directly to physical measurements of the well barrier quality.
An Automated Workflow for Real-Time Monitoring and Benchmarking of Connection Time in Drilling Operations
Authors: Karimi Vajargah Ali , Banirazi Reza , Pablo Mejia Juan , Haffner Phillippe 
Published: February 2020

Abstract
Invisible lost time (ILT) during drilling can add up to be extremely costly. Since a significant portion of ILT occurs during drilling and tripping operations (including running casing), the aim is to develop a workflow based on analytics algorithms that accurately identify and record how long it takes to make both drilling and tripping connections in real time using 1-second surface data. By capturing these KPIs, performance differences across the rig fleet were identified, and best practices were shared.
The developed workflow and algorithms for the drilling and tripping connection times can be applied to both active and historical wells in a fully automated fashion. The algorithm consumes 1-second surface drilling data to identify each connection. For more in-depth analysis, the drilling connection is divided into three stages: pre-connection, slip-to-slip, and post-connection. The algorithm relies on an advanced "rig state" (e.g., drilling, tripping in, tripping out, running casing) to determine the current state of the drilling process.
The algorithm was applied to more than 500 historical wells, drilled in three major business units in northwest Texas and southeast New Mexico. These wells had different levels of complexity, from shallow vertical wells to complex horizontal wells, and thus provided a very valuable data set for benchmarking and lookback studies. Through this process, more than 750,000 connections were identified. Analysis was done to determine a correlation between the connection performance and various factors such as rig type and contractor, crew, well design, hole depth, and drilling region. Best performers were identified for each unit to help determine the operational goals. The analysis showed that the drilling connection time varied significantly among different rigs, with a gap of more than 3 minutes for one of the business units, suggesting a huge improvement opportunity. In addition, the algorithm is currently being deployed at the rig site using the Internet of Things (IoT) Edge technology to run the application locally in real time and provide the drill site manager and driller with connection time, which had immediate impact on performance improvement.
The developed workflow in association with the algorithm, online visualization platform, and real-time monitoring, provides a powerful tool to improve efficiency, set realistic goals, make intelligent business decisions, and reduce the well delivery time without compromising safety. In addition, this study reveals that a reduction of up to 3% in drilling time of future wells can be achieved by lowering the current average connection time to the P10 value (best performers).
Drilling Performance Evaluation Using Advanced BHA Modeling and Field Validation
Authors: Greenwood Jeremy , Marck Julien , Nair Vakkeyil Naveen , Munguia Joseph 
Published: February 2020

Abstract
A methodology to optimize bottomhole assembly (BHA) designs to deliver improvements in wellbore quality has been developed. BHA modeling accurately simulates the drilling process and is combined with measurements of the wellbore to establish selected drilling key performance indicators (KPIs) leading to the successful optimization of BHA designs. The benefit of improved hole quality is to drill further, faster, and increase downhole tool life.
The methodology evaluates the drilling performance of mud motor runs using KPIs that evaluate the borehole quality and drilling performance. A BHA model evaluates the bending moment at critical housing locations at incremental measured depths. Changes in bending moment throughout the wellbore indicate variations in borehole tortuosity. Variation in borehole diameter during the slide and rotate modes identifies overall borehole rugosity. Multiple mud motor field runs in different basins in North America were analyzed to establish the KPIs. The tortuosity KPI results demonstrated the differences in borehole quality as a function of bending moment, where a tortuous borehole is attributable to increased bend ing moment. The fatigue life of the motor stator connections and the rate of life consumption with a larger accumulation of bending stress cycles was established. The borehole rugosity KPI demonstrated the increase in number of slide/rotate transitions, particularly in curve sections. In horizontal sections, the percentage of slide accounted for loss in rate of penetration (ROP) and consequently increased drilling time and borehole tortuosity. The combination of these factors was used to rank the different BHA designs in terms of their effectiveness to deliver a good quality borehole delivered in the least drilling time. Once the ranking was established, the effectiveness of each of the BHA design elements was established and this information used to improve the subsequent BHAs.
The approach creates a new performance evaluation methodology by combining both BHA modeling and field data to optimize designs. This methodology can be implemented before drilling to select the proper BHA design and post-job to evaluate a BHA designs performance.
Self Sealing Cement System Enables Prevention of Water Intrusion and Long Term Zonal Isolation in Um Gudair Field: A Case Study in West Kuwait
Authors: Jaffar Ali Hussain , Mohammed Jassem Ali , Khaja Mohammed , Haddad Hassan , Raturi Sushil , Albohamad Dalal , Abdel Lateef Emad , Aldakheel Rashed 
Published: February 2020

Abstract
Cementing the 7″ liner in UG field has always posed a great challenge due to the poor cement bonding across the target production zone, Minagesh Oolite. This is due to the high water influx, from the proximity of the aquifier drives to the production zone, hence leading to contamination of the cement slurry during the cementation. This has resulted in the loss of zonal isolation in addition to the unwanted water production. Water cut production has been observed to rise from 30% upto 70% and 90% within the course of less than 10 years. This has burdened a major Middle East operator with increased cost associated with remedial cementing jobs & disposal of water. Furthermore, conventional water shut off techniques, including cement plug back techniques, were proven to be largely ineffectual, hence an efficient control method was sought out as an alternative.
This paper discusses the implementation of an optimized, fit for purpose cement slurry, with enhanced mechanical and self-repairing properties along with the operational optimization in West Kuwait UG field which has improved the overall cement quality around the liner along with the reduction of water content (WC%) with production throughout a six month observation period.
An optimized, fit-for-purpose cement slurry system, with expansive and enhanced mechanical properties was developed and tested to simulate the conditions downhole during and after the 7″ liner cementation. Self-repairing, also known as self-sealing, and expansion properties in the presence of water and hydrocarbons were also tested by inducing fractures in the cement and observing the expansion and swelling capability in the presence of up to 90% water and only 10% hydrocarbon.
The self-sealing slurry was implemented in a step by step in a planned manner in UG field, with preset KPI's so as to evaluate the effect of slurry on water intrusion. Furthermore, operational execution and optimization was also considered to ensure a flawless cementing job execution.
Implementation of the first 3 self-sealing cementations of 7″ liner in UG field, showed great improvement in the cement bond log after 48hrs of cement placement. Further, the water cut in one case was reduced from 52% after initial testing to 24% and 22%, in subsequent 3 month and 6 month evaluation, respectively. This technology has also been used in other fields across Kuwait where water intrusion is apparent and different downhole conditions were observed. There is a large scope to use this technology as high water cut and poor cementation is a very common problem across different fields.
Fully Automated Managed Pressure Drilling Delivers Precise Control Through High Pressures in a Narrow Drilling Window
Authors: Muhammad Jamal uddin , Sugiarto Chajar , Hadj Moussa Ayoub , Kadadha Abdallah , Iturrios Carlos 
Published: February 2020

Abstract
Managed pressure drilling (MPD) helps operators efficiently navigate through narrow pore pressure-fracture pressure windows. The challenges encountered during one onshore drilling campaign included pore pressure uncertainty, high pressure influxes, total losses and high incidences of differential sticking, which at times led to abandoning wells when drilled conventionally. The case study highlights how these challenges were counteracted with the implementation of a fully automated MPD system.
MPD is a safer and more effective drilling technique, as compared to conventional drilling, especially in wells with narrow drilling windows and downhole hazards. A fully automated, early kick detection and control system that enables nearly instantaneous, precise adjustments to the bottomhole pressure adds great value to the client's operations.
It has been observed that in wells with a narrow window, precise determination of downhole pressure margins (i.e. pore pressure, wellbore stability and fracture pressure) and precise control of bottomhole pressure are imperative to complete the well without well-control incidents. A fully automated MPD system helps to achieve these goals.
Prior to the start of drilling with MPD, the exact formation pressure is determined by conducting pore pressure tests, and then during drilling the target bottomhole pressure can be precisely adjusted almost instantly by adjusting the surface pressure at the MPD choke. The MPD system greatly reduces the time to stabilize well conditions when encountering well control problems or downhole losses.
This paper summarizes the implementation of the fully automated MPD system as a sophisticated tool to precisely control such situations instantly, saving time, associated mud costs and hence optimize the overall drilling process. This paper describes a few MPD milestones in drilling the 8 3/8-in. and 12-in. hole sections in the field despite of difficulties including total losses and high-pressure influxes leading to well control events. The primary objective of MPD application in this field was to drill to the liner landing point by adjusting the bottomhole pressure (BHP) in real-time to eliminate the problems caused by uncertainty in the over pressured target formation and minimizing or eliminating the downhole fluid losses in the lower formations.
The paper describes results from two case studies. In the first case, the well was drilled with a 1 pound per cubic foot (pcf) (0.13 ppg) narrow window, with accurate detection and control of influxes while mitigating losses. In the second case, initially the bottomhole mud-losses were minimized instantly and later the well was precisely displaced under partial losses to a lighter mud to save mud costs while maintaining well control.
Hole Opening Challenges and Efficiencies – Interpretation and Implications of Bit and Reamer Dull Conditions
Authors: Mensa-Wilmot Graham , Woldtvedt Gust , Cardoso Marcos , Diwaku Wantuadi 
Published: February 2020

Abstract
Simultaneous hole opening with bit and reamer, based on acknowledged benefits, has become an drilling industry mainstay. Considering Bottom Hole Assembly (BHA) design and compliance requirements, bit and reamer in BHA, and issues with drilling parameters management, the operation presents severe drilling dynamics challenges. Additionally, several other factors initiate, sustain, and/or amplify dynamic dysfunctions. In their totality, these factors and conditions compromise hole opening efficiency, leading to increased cycle times and higher operational costs.
Current hole opening solutions and strategies have yielded inconsistent performances. Consequently, appropriate and effective solutions are needed to address above listed challenges. Data analysis must help identify factors and/or conditions that influence performance. These revelations must drive holistic solution approach for hole opening, that will be more effective at cycle time reduction, leading to project costs reductions. These expectations are only achievable, when appropriate implications are derived from effective interpretations of bit and reamer dulls. This paper will highlight and support these considerations with relevant field data, that focuses on hole opening efficiency factors, particularly dynamic dysfunctions. Cycle time effects and project costs considerations, as they relate to hole opening performance in challenging drilling environments will also be discussed.