bluuebunny/crossref_metadata_2025_split huggingface dataset:
Stiff String Casing Design with 3D Orientated Casing Wear
Authors: Nobbs Benjamin , Aichinger Florian 
Published: August 2022

Abstract
The forces and stresses along a casing string are modelled using a stiff string torque and drag model. A post analysis of casing loads and stresses, considering wellbore tortuosity and centralisation is performed in addition to the effect of 3D orientated casing wear. A post analysis case study is presented to show the resulting effect on axial, burst, collapse and VME safety factor as well as VME body and connection design envelopes.
While running in hole (RIH) a tubular, the industry standard is to assume a smooth wellbore when performing a torque and drag calculation. The drilling process can cause significant local doglegs and ultimately increase the tortuosity of the wellbore. When applying a soft-string torque and drag model, it is possible that the stiffness, radial clearance, and high frequency surveys are not directly considered. The stiff string torque and drag and buckling model can model these effects, as well as the addition of rigid and flexible centralisers. This study involves the comparison of different casing design load cases, using the actual tortuosity of a drilled wellbore considering a 3D orientated casing wear.
The results show that there can be noticeable differences in overall axial stress with the addition of tortuosity. The stiff string model can directly calculate the additional bending stresses experienced by the tubular and this additional stress can be particularly prevalent while RIH casing with centralisers and high tortuosity. The reduction in API and VME stress envelope is also quantified using a 3D orientated casing wear model. A better understanding of axial stress state reduces risk of well integrity issues and can pinpoint areas along the casing in which special care must be taken during well intervention.
This paper will show the benefits of using a stiff string torque and drag model during casing design. Highly tortuous wellbores, especially ERD and HPHT wells, may exhibit stresses that are vastly different than assumed during preplanning phase. The design API/VME envelope may also be reduced due to casing wear.
First Global Application Combining Digital Engineered Breakdown with Pulsing Technique for Highly Conductive Fractures with Proppant Agglomerates, Improving Subsurface Behavior and Maximizing Reservoir Productivity
Authors: Palanivel Maharaja , Khalifa Mohamed , Fuser Colby , Seada Mohamed , Farouk Eslam , Abdel Baky Ashraf , Abdel Sattar Ashraf , Ali Yehia , Maher Ahmed 
Published: August 2022

Abstract
To evaluate and report the benefits of artificial intelligence driven digital engineered breakdown in a pulsed fracturing technique that has been successfully applied for the first time globally in the western desert of Egypt.
In this paper, we will discuss how the artificial intelligence driven digital engineered breakdown can affect the production performance of a pulsed fracturing treatment. When formation breakdown is controlled, there are several benefits observed in the fracture geometry and its placement. However, this has never been applied in a pulsed fracturing treatment where creating a dominant fracture is believed to provide better distribution of proppant agglomerates allowing for enhanced fracture conductivity created by void space between the agglomerates. The productivity benefits of the engineered breakdown will be evaluated.
A treatment combining both the pulsing technique and the digital engineered breakdown will be reviewed in details such as well geographic data, reservoir quality, openhole log interpretation, pressure response and production models after matching actual data. The treatment will be compared with offset well that was treated with pulsed fracturing technique but without the digital engineered breakdown.
Better pressure response was observed during the treatment and higher proppant concentrations were accepted by the formation with much favorable pressure response compared to offset wells. Post frac well tests indicate excellent production performance for the given reservoir quality observed from the logs in comparison to offset wells.
Digital applications in fracturing have been recently improving the way we stimulate formations. This novel combination of pulsed fracturing and digital engineered breakdown shows productivity benefits that is crucial in current market conditions to maximize efficiency of operators assets.
A Case Study on the Use of Machine Learning and Data Analytics to Improve Rig Operational Efficiency and Equipment Performance
Authors: Curina Francesco , Asokan Ajith , Bori Leonardo , Qushchi Talat Ali , Mitu Vladimir , Mustapha Hadi 
Published: August 2022

Abstract
Ensuring an efficient workflow on a drilling rig requires the optimization of the equipment output and the extension of its working life. it is essential first to identify equipment behavior and usage and evaluate their possible efficiency variation. This can lead to predicting possible upcoming usage trends and proposing preventive actions like adjustment to equipment working parameters to improve its output and efficiency. In this regard, machine learning and data analytics provide a clear advantage. This paper showcases a case study that makes use of machine learning to detect rig inefficiencies and optimize operations.
The platform has been implemented to first collect the rig data and then process it before sending it to be analysed. The rig used in this case study was connected to a platform that makes use of Internet of Things (IoT) protocols. Noise and redundancy of the data coming from the rig were standardized, filtered and therefore the outliers were removed. Feature selection was used to highlight, from the data pool, the most significant parameters for forecasting and optimization. These resulting parameters were then sent to the machine learning model for training and testing.
The processed data was then fed to system, which was developed in-house, to extract additional information regarding equipment efficiency. This system tracks the variations in equipment efficiencies.
The study focuses on the performance of an HPU powering a hydraulic hoisting rig which was showing low efficiency. IoT technology was used to collect live data from the field. The gathered datasets were cleaned, standardized and divided into coherent batches ready for analysis. Machine learning models were used to evaluate how the workload would change with tweaks to working parameters. Then, the study analyzed the rig tripping speed and how it was connected to HPU performance. For evaluation of tripping speed, the focus was given also to small operational changes which could lead to improved performance. When connected together, changes to both operating parameters and standard procedures can lead to improved efficiency and reduced invisible lost time.
Implementing the results allowed the rig to be operated at a higher efficiency, thereby increasing the life of the equipment while keeping the load within design conditions. This ultimately resulted in a reduction in operational time and failure of equipment and hence a major decrease in down time of the rig.
Leveraging Digital Transformation in the Well Construction Planning Process
Authors: Suryadi Hendrik G. 
Published: August 2022

Abstract
The well-planning process involves many parties collaborating and optimizing various design aspects to deliver the best well construction. There are still many challenges for a well-planning team to manage the process and formulate the best drilling program. Many tasks are cumbersome and time-consuming; ensuring coherency within various parts of the drilling program is also difficult.
Digital transformation integrates digital technology to create new or modify existing workflows that can fundamentally change how we operate and deliver value. The oil and gas industry is expecting to redefine its boundaries through digitalization. Leveraging digital technology can act as an enabler to tackle various challenges, improve efficiency, and provide greater value in all aspects of the oil and gas industry, including a well-planning process.
In this paper, the author discusses various examples of how digital technology is used in well planning and how it changes our way of working, improves working efficiency, and delivers better results. Cloud technologies provide a new platform for collaboration and break the working culture in silos. It also provides a new way to communicate, share information, and eliminate multiple data transfers and manual inputs. Cloud computations can scale the computing resource elastically, enabling simple to complex modeling. Engineers can simulate various scenarios more quickly to decide the best plan. Various automation, from smart input to auto engineering analysis, are used to minimize mistakes, provide real-time feedback while designing, and improve working efficiency. The use of big data and machine learning can improve the accuracy of engineering analysis and provide an advisory model that can minimize the risk and uncertainty during execution. All these digital technologies are implemented in a cloud-based well construction planning solution.
Many other digital capabilities learned from other industry applications are also implemented to improve user experiences. Examples are a notification system, open architecture to connect to other databases and cross domain information, a digital review-and-approve system, traffic light validation system, multidimensional visualization, and automated report generation for the coherent drilling program.
Leveraging the digital transformation in the well construction planning process through a cloud-based application enables the planning team to maximize the results by giving them access to all the data and science they need in a single, common system. The solution increases planning efficiency and enhances well designs through automated end-to-end workflows, cross-company and cross-domain collaboration, auto-validation, and integrated offset knowledge; this accelerates continuous improvement of well construction activities.
Reservoir Compaction and Surface Subsidence Assessment to Optimize Field Development Planning in Offshore Malay Basin, Malaysia
Authors: Santha Moorthy Priveen Raj , Chatterjee Avirup , Younessi Ahmadreza , Ghosh Amitava 
Published: August 2022

Abstract
A geomechanical model calibrated to field data can be used to analyse the potentially severe impact of reservoir compaction on production. However, field data acquisition programmes can be expensive, and optimal reservoir monitoring design necessitates an understanding of reservoir dynamics. Forward geomechanical models can help establishing the appropriate field data gathering approach while reducing expenses and maximising value for model calibration. Significant reservoir compaction and surface subsidence have potential risks for fault reactivation, integrity of wells and surface facilities. This paper presents an integrated approach and workflow that combines geomechanically derived data, reservoir geometry and production data to predict reservoir compaction and surface subsidence throughout the life of the field. The results provide an essential understanding on the dynamics of production induced changes in effective stresses and formation mechanical properties and their impacts on the field development planning, risks mitigation and provision of contingencies for well construction and downhole and surface field monitoring requirements.
Continuous Improvement on the Performance of Innovative 360 Rolling Diamond Element and Conical Diamond Element Bit led to Save 2.9 Days from Drilling in Hard and Abrasive Sandstone Formation
Authors: Ngo Vi Lan , Khobchit Wanwarang , Teerachotmongkol Teerawat , James Biju , Abbasgholipour Ali , Kongsirinurak Thamonwan , Tungperachaikul Thanakorn , Amranand Sorawit , Panmamuang Nawapol 
Published: August 2022

Abstract
Mid Nam Phong Formation in Thailand’s Sinphuhorm Field consists of hard and abrasive sandstone with unconfined compressive strengths (UCS) of 12,000–24,000 psi. Polycrystalline diamond compact (PDC) drill bits used for the 8.5-in. section through this formation were providing low rates of penetration (ROPs) and showing heavy wear, with just 50–180 meterage drilled per run. Multiple bit runs were raising drilling costs. A new drill-bit design to address these challenges is presented.
Rolling cutter (RC) 616—an 8.5-in. drill bit with 16 mm cutters that rotate 360°—is holding the ROP record in offset wells, delivering 3.1 m/h compared with the average 2.15 m/h, a 44% improvement. Rolling elements use the entire circumference of the cutting edge to cut the formation, enabling them to stay sharper and longer. Conical diamond elements (CDE), which provide improved impact strength and greater resistance to abrasive wear, replaced some of the conventional cutters. Based on this result and lessons learned, a new and more robust bit design was proposed featuring 19 mm rolling cutters and conical diamond elements. To combat the damaging vibration observed in offset wells, which could further reduce ROP and increase the likelihood of premature drill-bit and downhole tool failure, a special bottom hole assembly that combined a rotary steerable system and a downhole motor was deployed to reduce stick/slip. Comprehensive simulations provided a detailed road map of drilling parameters that were used to minimize shock and vibration.
The new 8.5in. drill bit and BHA drilled the entire section through the Mid Nam Phong Formation in one run and at a record ROP of 4.9 m/h—58% higher than the maximum rate achieved by the RC616 bit—saving 57.8 hours. The assembly also drilled an additional 179 meterage into the Lower Nam Phong Formation, eliminating the separate bit run that had been required in offset wells. The customer saved 2.9 days or USD 130,000 in total and a new standard of drilling performance was established.
The new concept of PDC bit combining 19 mm rolling cutters and conical diamond elements expands the limit of PDC bit durability drilling hard and abrasive sandstone formation. This new type of bit can efficiently drill in those challenging geological condition reducing the drilling time and cost.
This paper will discuss the application and evolution of rolling cutter bits, along with the results achieved by this bit.
Advance Nuclear Magnetic Resonance and Image Logs Application for Predicting Particle Sand Distribution
Authors: Samuel Elvy Jose , Hanif Mohd Shah Redza , Mustapa Muhd Syaiful Azman , Adeyosfi Merza Media , Lwin Moet Moet , Lee Samie Sok Foon , Millot Pascal , Wong Fui Kent 
Published: August 2022

Abstract
The complexities of designing an effective sand control for unconsolidated gas reservoirs in a deepwater environment is exacerbated when the targeted formation sands are characterized by particle size distributions with poorly sorted and non uniform coeficients, and high fine concentrations. Managing these intricacies requires comprehensive sand retention studies developed to ascertain the effectiveness of the sand control performance of gravel and screen gauge opening combinations in the presence of selected formation sand ratios. To build a representative testing program, actual core samples from the targeted studied zones are desirable. However, for economical, technical or logistic contrains the availability of these cores is not always feasible. This paper covers a workflow to determine a synthetic Particle Size Distribution (PSD) of a targeted well in a development block where no core data is available. The data feeding the workflow is derived from wireline bore hole imagers and Non-Magnetic Resonance (NMR) logs obtained from six wells drilled in the exploration phase of the studied gas block. Results are calibrated with localized PSD from available side wall cores. Furthermore, data obtained from the process is used to interrogate sand retention testing Mastercurves built with formation samples from one of the fields in the studied block (Field I). The interrogation process takes the synthetic PSD from the targeted well and creates normalized formation testing ratios which are then compared to the results documented on the sand retention Mastercurves. This paper is intends to discuss the worklflow and results of its field application.
An Innovated Image-Based Approach for Logging-While-Drilling Image Quality Improvement in Stick and Slip Phase
Authors: Yang Shiduo , Al-Mutairi Fayez , Zhang Tianhua , He Alexis , Shrivastava Chandramani , Shim Yen Han , Taufik Pasaribu Ihsan 
Published: August 2022

Abstract
Stick/slip motion is an extremely severe torsional oscillation that can cause the drill bit to come to a complete stop and then followed by an extra acceleration of the surface rotation. Due to the lack of downhole sensors for direct speed measurement of logging-while-drilling (LWD) image tools, the depth measured on the surface can appear to be smoother than the downhole sensors’ real movement. Using the smoothed surface depth for time-to-depth gating of the images might lead to the formation features appearing to be compressed or stretched semicyclically in the depth domain when sensor stick/slip occurs.
In this paper, an innovated approach is presented to restore image features altered by the depth desynchronization and stick/slip issue. This method initially identified the drilling status from the interpolated surface depth in a time domain, including sensor movement direction; i.e.,drilling down or reaming down, tool stop, and connection breakdown time. In parallel, the drilling statuses were also identified from a downhole image feature similarity and the artificial intelligence (AI)-aided functions. The surface depth can be synchronized to downhole image measurements in the time domain based on the identified drilling statuses. In the end, the stick/slip time intervals were identified from the synchronized depth when the depth variation exceeded the image's vertical resolution, and the pseudovelocity was filtered and computed in the time domain. The stick/slip image features were restored in the depth domain efficiently after time-to-depth gating using the new processed depth.
This new approach will be applied to an LWD ultrasonic image obtained from a Middle East carbonate reservoir. The drilling statuses were identified confidently in the time domain and no additional stick/slip features were found in the image data in the depth domain. The processed images revealed the reservoir heterogeneity with clear vug features, additional bedding boundary, and confident fracture features.
In a severe stick/slip mode, the LWD resistivity image was processed with downhole speed correction from the multiple sensors’ signal, but the block image features remained on the image in the depth domain. The image features were restored efficiently with an adapted solution from this innovative approach.
Longest 3D Horizontal Granitic Basement Section Record Drilled in Vietnam Using Friction Reduction Technology and Real-Time Torque & Drag Management
Authors: Thai Lam , Nguyen Nam , Blackwell Geoff , Do Minh 
Published: August 2022

Abstract
Granite basement drilling in Vietnam is well-known for challenges such as slow penetration rate, strong drill string vibrations, and multiple bit runs required to finish the section. A 3,217 m length 3D horizontal basement section was successfully drilled in 2017 by applying a new drill string optimization method in combination with using axial oscillation friction reduction tools (AOT), reaching total depth (TD) at 6,280 m measured depth (MD). This run represented the longest 3D lateral well drilled in Vietnam at the time (please reference the SPE-191872-MS). Based on the success of that project, Thang Long Joint Operating Company planned to drill a new well with a longer reach to farther targets as per subsurface objectives to extend the record to a planned 3,543 m 3D horizontal granite section hitting three reservoir targets. The directional plan included building inclination from 19° to 88°, turning from 97° to 57° azimuth, and then turning horizontally from 57° to 16° azimuth, with planned TD at 6,768 m MD.
With the field-proven drill string optimization method from the offset well, a torque and drag model was built for the subject well in order to understand the difficulty and feasibility to reach the well TD. This model was used for drill pipe selection and configuration, as well as AOT planning purposes, and it was continuously updated in real-time throughout the well. A newer and more efficient version of the AOT technology was introduced to help increase the effectiveness of the friction reduction to help reach the planned TD. From the modeling results, drilling to the planned TD was considered achievable, even when applying worst-case scenario drilling conditions.
In terms of trajectory and timing, the actual drilling operation was well-matched with the planning. The selected drill string designs using single AOT systems and dual AOT systems performed as expected and were instrumental in achieving the planned TD. A total of 15 roller cone insert bits and steerable motor BHA's were used to drill the section. From 5,509m MD, due to the high drag condition, dual AOT systems were utilized to aid in weight transfer to the bit to drill to the well TD at 6,768m MD; the longest 3D horizontal basement section drilled in Vietnam to date.
The success of the project once again proves that axial friction reduction technology is a reliable technology for drilling the granitic basement in Vietnam, on time and within budget.
Study on Fracture Propagation Simulation with the Integration of Fully-Coupled Geomechanical and DFN Modeling
Authors: Li Wei , Xing Yangyi , Zhang Haijie , Luo Tongtong , Li Wenhong , He Jinpeng , Huang Xingning , Singjaroen Thanapol , Kieduppatum Piyanuch 
Published: August 2022

Abstract
Shale gas reservoirs are characterized in low gas abundance, poor permeability, lower natural productivity than the lower limit of industrial oil flow, and rapid formation energy decline. At present, the technology of horizontal well drilling and staged hydraulic fracturing is widely used for the exploitation of such low-porosity and low-permeability reservoirs. The long well section of the horizontal well in the reservoir and the hydraulic fractures formed by fracturing act as the "underground expressway" for the deep gas in the reservoir to flow toward the wellbore. Their combination can greatly increase the production performance of the oil and gas resources in the reservoir. Staged multi-cluster fracturing in horizontal wells is the key technology to achieve the profitable shale gas production. The results of on-site downhole perforation imaging and distributed optical fiber temperature and acoustic monitoring show that there are obvious non-uniform liquid inflow and expansion phenomena in each cluster of fractures during the fracturing process. Relevant research results also show that factors such as the heterogeneity of the reservoir and the stress interference caused by the propagation of multiple fractures are the main causes of the non-uniform propagation of hydraulic fractures. Therefore, it is accessible to simulate the complex balanced expansion of each cluster of fractures in the fracturing section to improve the coverage of hydraulic fractures in the horizontal well section with numerical simulation methods based on the basic theory of elasticity and fracture mechanics, to reveal how the above engineering geological factors influence and control the fracture propagation. The results of the simulation of the fracturing treatment section of the deep shale gas horizontal well by the fracture propagation model are consistent with the micro-seismic monitoring results,which has obvious significance for accelerating the exploitation of difficult-to-exploit resources and guaranteeing the supply of gas resources.