bluuebunny/crossref_metadata_2025_split huggingface dataset:
Applying a Downhole Drilling Mechanics Tool to Improve Operational Procedures and Rig Operating Systems in Horizontal Wells
Authors: Fonseca Isaac S , Isbell Matthew , Groover Austin 
Published: March 2023

Abstract
Managing drilling dysfunction is key to safely drilling horizontal wells in harsh environments. However, extended horizontal wells with long open-hole intervals complicate identifying and addressing dynamic drilling problems using surface measurements. The latest generation downhole drilling mechanics tool uses high-frequency measurements to characterize drilling patterns and dysfunctions in turn, is used to improve rig operational practice and drilling system design.
This paper describes how to capture and analyze downhole drilling data sets, identify areas for improvement, and address them by improving operational rig processes and the drilling system design. The approach is applied with two different operators using two different rig operating systems with two different contractors in two different basins with varying systems of drilling and muds. The drilling process is characterized in different ways, and energy management is closely evaluated using surface and downhole measurements for a comprehensive system perspective.
The authors break down operational activities into processes and apply process improvement concepts to improve drilling outcomes regarding safety, quality, delivery, and cost. The process improvements are sustained by a combination of drilling system design improvement and drilling operation process automation. Examples of the processes improved throughout a well are the repetitive activities completed during drilling a stand of drill pipe (typically about 95’ in length)), an on-bottom transition with the drilling assembly, rotary drilling, and slide drilling operation with conventional steerable systems, and an off-bottom transition. The improvements have saved a trip for two- and three-mile horizontal sections where multiple runs are typical.
This paper describes and demonstrates a repeatable approach to using the drilling rig system, downhole drilling system, and body of operational practice to break down the drilling of an interval into processes for improvement. Using a downhole drilling mechanics sub to characterize energy management and qualify operational practice allows a process improvement approach to managing downhole behaviors with drilling rig control systems.
Real-Time Directional Guidance Through Cloud-Based Well Path Optimization
Authors: Joshi Deep R. , Kamyab Mohammadreza , Cardoso Braga Daniel , Cheatham Curtis Alan 
Published: March 2023

Abstract
This paper shares an implementation of a cloud-based framework that tracks the well position and, in real-time, recommends corrective actions to ensure that the well efficiently follows the well plan. This directional guidance framework can differentiate between vertical, curve, and lateral sections and modify the recommendations accordingly. This paper will share the methods and results from the case studies to validate the directional guidance framework.
This cloud-based directional guidance workflow kicks in as soon as the drilling starts. In real-time, the system tracks the bit position and identifies the active section (vertical, curve, lateral, tangent) for the well. Vertical and lateral sections use recommendations previously reported using particle swarm optimization in SPE-206170 (Cardoso Braga et al., 2021). Equations for curve sections are provided that fit the proposed wellbore trajectory to a 3D spheroid using the current motor yield as calculated using the three most recent slides. A real-time assessment of the estimated actual landing point is presented, and warnings of missing the planned landing point are provided.
The drilling guidance algorithm was tested for individual sections (vertical, tangent, curve, lateral) on three wells. The recommendations were evaluated to ensure they met each section's optimization goals. The optimization goals for the straight sections are to maximize the ROP, maximize the footage in the window, and minimize tortuosity. Weighting factors for each goal adjust the optimum recommendations based on user requirements. The optimization goals for the curve section are to minimize the distance between the planned landing point and the recommended landing points Then, the guidance system was tested on the complete wells to ensure that the algorithm could correctly identify the section and use the appropriate method. The recommendations from all three wells were evaluated to confirm that the recommendations met the specific criteria applied. Close attention was paid to the transition zones between various sections. The directional guidance workflow resulted in real-time recommendations throughout the well profile for all sections. It was consistently able to output specific steps that the directional driller can take to optimally get closer to the plan.
This paper follows up on the previous publications on directional guidance by the authors (SPE 206170 (Cardoso Braga et al., 2021) and SPE 204065 (Cardoso Braga et al., 2021).). It completes the loop on automated directional guidance by adding the missing piece of directional guidance in the curve section and handling transitions between straight (vertical, lateral, tangent) and curve sections. This enables cloud-based automated directional guidance for the entirety of the drilling process.
Learnings from Successful Drilling in Heavily Depleted HPHT Reservoir with Up to 460 Bar Depletion
Authors: Heggheim Trond , Andrews Jamie 
Published: March 2023

Abstract
Gudrun is a high-pressure, high-temperature (HPHT) field on the Norwegian Continental Shelf which has been in production since 2014. The initial development called for predrilling of the producers prior to commencement of production through depletion drive. In 2020 a second drilling campaign was initiated where the goal was to drill several infill producers and two water injection wells. The issue of drilling in heavily depleted reservoirs was highlighted as a major risk since depletion in some of the layers was expected to be in excess of 450 bar. The operational window was small and uncertain, and several risks were anticipated. Differential depletion in this highly layered reservoir, with the potential for penetrating both heavily depleted layers and non-depleted layers, meant that drilling and completion operations required wellbore pressures in excess of the minimum stress in the heavily depleted layers. There was thus a significant risk for lost circulation and escalation to possible well kick/underground blowout events. To mitigate these risks several actions were taken including Managed pressure drilling (MPD), splitting reservoir drilling into several sections, drilling of near vertical reservoir intervals and the use of active Wellbore Strengthening (WBS)/ Lost Circulation Material (LCM) particles in the mud. The use of optimal background WBS particles was complicated in the first two wells due to risk of plugging of lower completions upon production and so compromises were required to the particle sizes that could be used. This paper summarizes the experience from the successful drilling of these infill wells. It confirms that the use of WBS particles is critical in providing a robust drilling window against losses when the Fracture Gradient (FG) is reliant on near wellbore processes and elevated hoop stress around the wellbore to support downhole pressures that exceed minimum stress deeper in the "body" of the depleted layers. The experience on Gudrun also suggests that the FG is sensitive to the temperature of the mud when drilling the stiff Gudrun layers. The influence of depletion on the minimum horizontal stress, as determined from this drilling campaign, is also discussed and this is related to rock mechanical tests performed on core plugs from the field.
Software-Based Three-Dimensional Scan of a Drill Bit; Advances in Technology and Applications
Authors: Chatar Crispin , Mulchandani Kishore 
Published: March 2023

Abstract
The ability to create a digital avatar of real-world equipment opens the possibility to create various levels of digital and virtual twins. Pairing these with real-time data can be a powerful tool to understand the life cycle, track operations, and collect data to predict the health of equipment. We have been testing new software methods to enable the use of existing technology to generate avatars for equipment. While many companies are also doing this with complex hardware, we have been using new software methods so that hardware requirements could be as simple as a common cell phone. We have applied these techniques to drill bits. The result is an application that creates a three-dimensional reconstructed model of a bit. This creates an avatar of the drilling bit that can be used for many purposes including equipment tracking and data extraction.
Results from the three-dimensional reconstruction and the automating of a simple linear pipeline that converts bit videos to three-dimensional models is demonstrated. The renderings were compared to photos at the same locations and the results were virtually indistinguishable. The models can then be used for virtual twin generation. Multiple scans over the lifespan of the drill bit will allow access to a new way of thinking about virtual twins. One example is the ability to update a model with a snapshot in time and use AI to infer the life of the bit. These models can also be used to run additional analysis since the model can be infused with some contextual information.
A Field-Proven Approach to Decreasing Survey Times During Connections While Drilling
Authors: Hempel Markus , Helle Nils , Shah Ibrahim Asghar , Fuhrwerk Martin , Quach Anh Vu 
Published: March 2023

Abstract
Reducing connection time while drilling has been a critical task in any drilling operation to reduce both the rig costs and the risks of wellbore instability. One way of reducing the connection time is to decrease the survey times. This paper shows a novel way to accomplish this by using a two-fold approach: an enhanced bottom-hole assembly (BHA) start-up procedure and secondly, a modified algorithm on the mud-pulse telemetry (MPT) uplink decoding software.
The enhanced measurement-while-drilling (MWD) BHA start-up procedure focuses on various process steps during the flow-off and flow-on phases. Start-up is, historically, a sequential process. The enhanced start-up procedure uses parallelized discovery of components (nodes) in the BHA, accelerated directional survey calculation, and dynamic rather than static timing of handshaking between nodes.
The MPT uplink (the communication of downhole information to surface) decoding improvement focuses on identifying delays in the signal processing chain. The detection of the MPT uplink synchronization sequence with an enhanced correlation approach shows the biggest potential in delay reduction.
The latest fleet of MWD BHAs contain an implementation of the new approach, successfully deployed for multiple customer wells in the US, Saudi Arabia, China and Mexico. These wells cover multiple well types, e.g. unconventional, hard rock and high-temperature. In total, deployment of BHAs containing the new approach in over 125 wells achieved an average of 25% reduction in survey times. These deployments have not shown compromised survey quality or decoding capabilities. Rather, the robustness of the synchronization sequence permits, in some cases, going on-bottom and drilling before synchronizing the uplink. Specifically, this has given customers the potential to drill miles-a-day wells more frequently.
An additional advantage of the reduced latency in the MPT uplink is that all MWD or logging-while-drilling (LWD) data is available earlier rather than later, thus allowing more timely decisions and in the end reducing risk.
Safe, Robust and Efficient Through Tubing Abandonment
Authors: Van Riet Egbert , Lucas Alex , Roijmans Roel , Keultjes Wout , Agnew Alistair , Benmesbah Mohamed Oukil , Houghton-Evans Simon , Evans-Guthrie Caroline , Potze Robert Jan , Keenan Jim , Meng Meng 
Published: March 2023

Abstract
There is a growing need for robust and efficient abandonment approaches with many oil and gas reservoirs nearing their economic lifetime. The Through-Tubing Abandonment (TTA) approach can deliver safe, robust and efficient isolation and reduced environmental footprint in keeping with ‘As Low as Reasonably Practicable’ (ALARP) principles. This paper provides guidance on how to select TTA candidate wells, including wells with gauge cables present in the permanent isolation interval, and provides operational advice to obtain a quality abandonment.
The industry has been abandoning wells via through tubing cementing methods for decades which has resulted in significant progress in the understanding of the applicability of the methodology and commensurate development of suitable technologies to deliver reliable long-term isolation. This paper will present the latest on selection criteria to screen wells for TTA. It will further propose cement placement and verification methods, necessary barrier lengths and risk-based decision making on the acceptability of gauge cables as part of the final permanent well barrier element.
The recent insights in TTA technologies and their use are described. These include demonstrated technologies such as expanding cement and vibration tools to enhance cement placement and options to log and verify the isolations. Testing results on cement sealing with gauge cables incorporated in the cemented annulus are also presented. Furthermore, promising emerging technologies such as methods to centralize the tubing to improve cement placement will be described.
Recent TTA applications in Europe, onshore and offshore, are presented as examples to illustrate current industry experience and the viability and reliability of such approaches.
A generally accepted, safe, robust and reliable approach towards TTA in keeping with ALARP principles common to the industry is pursued within this paper in order to enable acceptance and growth of TTA and associated technologies, and thereby further enable the wider application of rigless abandonment across the industry.
IADC Dull Code Upgrade: Photometric Classification and Quantification of the New Dull Codes
Authors: Gjertsen Ole , Mushinski Ryan , Wolfram Preston , Leisey Jeffrey , Bandi Mani , Santana Roberta , Andreasen Gregory , Pastusek Paul , Daechsel Dustin 
Published: March 2023

Abstract
In the world of drilling, the drill bit dull condition contains our best forensic evidence of the drilling assembly's interaction with the formation. Dull grading forensics is the first place to look to identify drilling dysfunction yet commonly overlooked or misunderstood by operators. The drill bit dull condition can be leveraged to learn about the formation, drilling dynamics and drilling practices (Watson et. al. 2022).
The IADC bit dull grading classification system received its most recent revision in 1992 and currently consists of an average inner and outer dull grade severity, rated from 0 – 8 with a major and other dull characteristic along with a reason pulled. These grades can be used to make critical operational and bit design decisions to overcome drilling challenges thereby improving performance and allowing drilling teams to drill consistently further and faster.
The oil and gas industry is becoming more reliant on digitally enabled applications to improve performance through big data, machine learning and automation, but at the time of this paper, the critical IADC dull grading system has remained the same. It is still a crude and subjective characterization of the complex drill bit dull condition.
A key challenge with the current classification system and industry standard grading technique is that it is highly dependent on the person grading the bit. Personal subjectivity and lack of training can result in key forensic evidence being overlooked that otherwise could have aided in understanding the root cause of drilling dysfunction.
A cross disciplinary committee of subject matter experts (SME's) from operators, drill bit providers, cutter manufacturers, and digital solution providers have convened to define and introduce a new standard dull grading system as replacement for the current outdated IADC dull grading. The new dull grading system will allow for an objective cutter-by-cutter dull grading to be stored with relevant drilling data with reduced subjectivity and enhanced accuracy.
With recent advancements in mobile phone hardware and applications, a solution was developed that delivers high quality, cutter-by-cutter dull grading automatically and connecting with drilling meta data from a drilling records database containing over 1.8 million well records with over 5 million bottom-hole assembly (BHA) runs. It leverages videos with machine learning combined with an algorithm to deliver cutter specific, major dull characteristics of a scanned bit. This high quality photographic digital dull information is incorporated into workflows allowing for rapid improvement in cutting structure and cutter development lifecycle timelines leading to rapid improvements in drilling performance for operators.
An Innovative Workflow for Real-Time Torque and Drag Monitoring
Authors: Sun Kewen , Mu Chao , Yu Tao , Paterson Graeme 
Published: March 2023

Abstract
Abnormal torque and drag (T & D), which commonly includes overpull, underpull, and high-torque load, are indications of excess frictional effects between the drillstring and the wellbore walls. Numerous conditions can cause these effects, including tight hole, differential sticking, poor hole cleaning, key seats, etc. Failure to observe these anomalies will cause excessive wear on the drillstring and can eventually lead to severe stuck pipe conditions. A new workflow for monitoring T & D is presented in this paper. This workflow, developed for a real-time monitoring system, allows for monitoring various types of data from multiple sources to be received without delay, aligned, and synchronized.
The workflow requires standard surface measurements and contextual data, which are available on most wells. Three main segments with respect to the computation phase are included in the workflow. These segments include T & D measurement points statistics, T & D modelling and calibration, and abnormal T & D alarms. The measurement points are selected from relevant operations and summarize the statistics at different granularities to meet the different objectives, such as the classical broomstick plot or alarm triggering. A hybrid T & D modelling framework was designed to predict the hook load and surface torque accordingly. This framework combines the mathematical capability of a stiff-string model using a finite element method and the experience acquired from obtaining the drilling data. As a result, the physical model can be automatically calibrated and driven by real-time data to compensate the hook load offset due to uncertain variables or inaccurate inputs. An alarm-triggering logic can be developed to capture anomalies based on a comparison between the measured and predicted values.
The new workflow is fully automatic without a need for manual calibration and fixed thresholds. Furthermore, the workflow adjusts itself according to real-time observations, which makes it adaptive to the changing conditions of the well being drilled. The efficiency and reliability of the anomaly detection heavily rely on the input data quality in the perspective of stream computation. In this paper, two case studies are presented containing the results produced by streaming actual well data in a time series manner. The case studies demonstrate the usability and reasonableness obtained by the user when handling the actual operation scenarios.
The work presented in this paper was developed to meet the increase in digital transformation by the oil and gas industry and demonstrates the best use of data for drilling optimization.
Quantifying the Sealing Performance of Plug and Abandonment (P&A) Cement Systems under Downhole Conditions
Authors: Roijmans Roel FH , Wolterbeek Timotheus KT , Cornelissen Erik K , Keultjes Wout JG 
Published: March 2023

Abstract
Micro-annuli are an important cause of post-abandonment seepage along abandonment plugs set in wells. Autogenous cement shrinkage, occurring when the cement sets, is a contributing factor to the formation of such flaws. Cement shrinkage and its potentially deleterious effects can be mitigated by using a properly designed and placed expanding cement system.
Reliable evaluation of cement plugs’ sealing performance requires testing under elevated temperature and pressure conditions representative for downhole conditions. In this contribution, two lab setups designed for this purpose are described, namely: i) small-scale tests on 2″ plugs and ii) large-scale tests on 8″ plugs. In both setups, plugs are cured and tested under downhole conditions inside sections of steel pipe. These pipes are equipped with lateral pressure-temperature sensors, which allow the recording of stresses that develop on the cement-steel interface when a hydrating cement plug is trying to expand. Using this industry-leading equipment, a strong positive correlation was found between the amount of interface stress build-up and the sealing performance of the set cement plug against gas flow. This demonstrates that cement systems which expand effectively under downhole conditions can reduce post P&A seepage risks.
While providing valuable insight, the 2″ and 8″ plug setups are labor intensive to operate and hence impractical to use in field labs for cement slurry verification. Unfortunately, standard industry methodologies to verify the effectiveness of the cement expansion additives does not take into account in-situ well conditions. To allow the industry to still evaluate cement plug sealing performance with low complexity, while maintaining reliability, a conventional ultrasonic cement analyzer (UCA) was modified to enable simultaneous measurement of interface stress development. Similar to the 2″ and 8″ plug sealing evaluation setups, this modified UCA vessel was equipped with a lateral pressure-temperature sensor, in order to monitor interface stress between the cement and vessel wall with time.
For this contribution, multiple cement slurries were cured and evaluated in the 2″ and 8″ plug evaluation setups, as well as in this newly developed "modified UCA vessel". Strong correlations were found among the stress build-ups in all three setups. This enables the modified UCA test results to be used as a proxy for sealing performance of P&A cement plugs under downhole conditions.