bluuebunny/crossref_metadata_2025_split huggingface dataset:
Smart RTOC: Pioneering Precision in Oil & Gas with Dynamic Digital Twins
Authors: Karpov R. B. , Starchunov M. S. , Kojadinovic N. , Kokotovic U. , Valiullin K. 
Published: November 2024

Abstract
The article describes the implementation of a full-cycle well construction support approach within a unified Digital platform that includes well design, real-time operational support, and job performance analysis. Derived analysis results are utilized in planning of subsequent drilling operations, thus closing the loop of continuous improvement.
The platform generates a drilling road map on the predrill phase utilizing T&D and hydraulic design, KPIs and metrics statistics, and offset wells best practices, collected at all stages of well construction performed within the Digital platform. During the execution phase, the platform utilizes advanced real-time monitoring tools to ensure predictive analytics and mitigate complications through proactive decision-making. Post-job phase includes KPI analysis and operational parameters target indicators definition for future wells. This comprehensive approach covers the entire well construction process, from planning to execution and analysis, facilitating continuous improvement and optimization.
The platform gathers offset wells data on each phase including T&D and hydraulics analysis results, real-time digital twin calculations and statistics on operational parameters. This enables flexible adjustment of KPIs and metrics for further analysis. The platform utilizes various metrics, conducting advanced comparison analyses of operational parameters derived from surface sensors and digital twin calculations, correlating drilling dysfunctions with geological formations and operational envelopes. This facilitates precise identification of potential improvement zones and their dynamic assessment during subsequent well drilling. Identifying potential improvement zones during post-job analysis, incorporating these results into drill planning, and real-time operational control during job execution lead to a reduction in Invisible Lost Time (ILT) and maximization of economic benefits.
The implemented approach was applied in the contractor’s facility while drilling 20 wells simultaneously under similar geological conditions. Real-time Operations Control Centers (RTOC) personnel noticed the effectiveness of utilizing digital platform combined with well planning, real-time monitoring and advanced analysis. The Managing framework for the continuous improvement cycle within a unified Digital platform described in the article will be beneficial to a wide range of users.
Mapping In-Situ H2S in Carbonate Khuff Reservoirs in Central Oman
Authors: Suut N. S. A. , Shukri K. , Ghammari M. , Borbajo R. 
Published: November 2024

Abstract
H2S is a colorless toxic gas, although harmless in minute quantities, it can pose HSE critical hazards to personnel and facilities if risks are not identified and managed appropriately. Drilling through H2S bearing intervals and production from sour reservoirs require H2S mitigations eg. Emergency Planning Zone (EPZ), Simultaneous Operations Classifications (SIMOPs), materials and to have facilities adequacy assessment in place. Carbonate Khuff reservoirs across Oman exhibit variations of H2S from sweet to sour concentrations up to 8% (80 000ppm). This paper discusses workflow, data gathering, acquisition results and learnings, and thus de-risking of H2S in Khuff carbonates across Central Oman. This study would also be complementing PDO's Guidelines of pre-drill H2S Prediction Best Practices. A review of reservoir fluids and properties, available key H2S data, any drilling well events involving H2S, were conducted and inventoried across nine (9) fields across Central of Oman. Where data gaps were identified, extensive sampling and analyses were conducted, these included surface and subsurface sampling, geo-chemical finger printing and sulphur isotopes analysis. Regional correlations were conducted across these fields on Khuff and its subdivisions and depth maps indicating potential Khuff closures and fluid fills were generated. In terms of understanding fluid fill, pressure gradient analysis has also proven inconclusive to predict fluid type due to the tightness of the formation with mobility &lt;1 mD/cp. While it is expensive, fluid identification and downhole sampling is the most reliable method to test the fluid type in Khuff. All this information was catalogued and integrated to generate H2S map across Central of Oman. Understanding of origins of H2S in Khuff was still challenging. It was observed that there were lateral and vertical variations across the fields in Central Oman. In some cases, even within the same field (Field A), one well was observed to be sweet while the other was sour. Prior to this study all wells’ planning carry the high case assumption of sour Khuff of Field C as their analogues. As a result, all wells penetrating Khuff intervals (total of &gt;200 wells to be drilled in the next 5 years) were classified as DWI-3 classifications and sour well control requirements need to be applied. New data acquisitions identified and executed allowed the team to map H2S across fields in Central Oman. The results concluded that only lower Khuff is sour and upper Khuff is sweet in some fields. Business impact of the study: H2S ranges uncertainties gap had been reduced and appropriate ranges had been used for well design and planning, adhering to H2S standards SP-1190-2, only &lt;15% of the total wells planned in the next 5 years are considered as Sour DWI-3 well classifications, optimizing cost and time.
Implementation of Comprehensive Engineering Approach to Enhance Drilling Performance – Case Study of Drilling Intermediate Section in Offshore Field Abu Dhabi
Authors: Handoko A. I. , Cotton M. , Yudhia D. , Biyanni H. , Singh R. 
Published: November 2024

Abstract
This paper outlines a comprehensive methodology to tackle challenging operation of drilling 12-1/4" hole section in one of the offshore field Abu Dhabi. This hole section is highly prone to various problems where significant Non-Productive Time (NPT) and Invisible Lost Time (ILT) have been recorded. Thus, the drilling team is seeking for a novel fit-for-purpose approach to deliver operational excellence systematically through continuous performance improvement.
Drilling performance support group assist drilling engineering team by providing an integrated real-tome operation monitoring, reporting, and advanced BHA simulation capabilities. Initially the problem was identified as high BHA failure rate caused by varying vibration modes coupled with hole cleaning and wellbore instability. BHA simulation and Geomechanics modelling were then performed on past wells to identify the root causes of each failure event. These analyses leverage High Frequency (HF) operation data recorded through Real-Time function. Performance reporting is then presented through interactive dashboards accessible by all drilling team members. These steps are performed with dedicated tools to improve the team's efficiency while simultaneously reduce gross errors.
The methodology was first implemented back in 2020 with real-time monitoring and reporting functions. BHA simulation and geomechanics modelling capability were included in 2021. The simulation provided the most optimum BHA stabilization configurations for each well profile. Geomechanics study allowed a calibration on Mud Weight and bridging material properties to limit borehole collapse and assist in cuttings evacuation. The full implementation has improved the performance through 14% reduction in ILT, 80% reduction in hole problem and stuck pipe cases, and 64% reduction in BHA failure rate, allowing the team to deliver more well based on annual target. The promising results indicated by the ILT and NPT figures allowed the operator to extend the 12-1/4" envelope further, which already captured in future well plans.
This methodology has brought a greater technical understanding for the drilling team to deliver overall improvement in 12-1/4" hole section. A dedicated performance groups allows the provision of effective support for drilling engineering and operation teams. This approach allows each team to focus on their primary objective in parallel.
Optimizing Waterflood Review through an Integrated Platform; An Example from the South of Oman
Authors: Borkent E. , Al Mahrouqi J. , Agrawal R. , Al Kindi N. , Al Muzaini N. , Al Hatmi F. , Al Khayari H. , Al Busaidi I. , Sallam M. , Cristancho D. , Al Mahqouqi L. 
Published: November 2024

Abstract
One of the critical success factors of waterflood developments, is how efficient the dynamic management of its operating envelop is. While data availability may not be an issue, the challenge remains in effectively and frequently integrating and interpreting all relevant up-to-date data, e.g. injection, production, pressure, voidage replacement, etc. Having these visualized and dynamically updated in one platform with pre-defined workflows and metrics will allow easy identification of performance gaps and will make decision-making a more straightforward process.
A successful application of the one-platform-approach is shown in a sandstone waterflood field in the South of Oman. It consists of over 20 inverted nine-spot patterns operating under matrix conditions. The online webpage platform provides an immediate hierarchical overview of pressure and sweep performance with automated recommendations on further injection optimization. At field level, property bubble maps, intake- and offtake trends with well averages are visualized. At pattern level, performance is ranked based on the pattern sweep efficiency and reservoir pressure. Zooming to the well level; allocated performance trends are easily accessible and linked to the injector performance.
With the offered minimal data gathering and processing time, the waterflood performance reviews become a more frequent and easily accessible multi-disciplinary task. The automated pattern and well performance ranking with the built-in recommendations, based on the pre-defined limits in pressure, injection, voidage, etc. allow faster mitigating actions in areas of concern. It also provides quicker guidance of where further optimization in throughput can yield better conformance in sweep and pressure. Having the performance visualized in the geological and petrophysical maps readily highlights if the shortage in performance is linked to the reservoir quality or to the assumptions of the connectivity between the producers and the injectors. With the data seen in both time and space, gaps in surveillance, e.g. static pressure surveys, are easily identified.
The integrated platform helped identify multiple opportunities to improve field performance; VRR moved from 0.6 to 0.9 with oil production increasing by about 5-10%, arresting the field decline.
This approach adds to the continuous efforts in the oil industry to better manage waterflood developments within their operational constraints while aiming to maximize sweep and maintain a healthy pressure picture. It gives a holistic and hierarchal workflow allowing integrated understanding of the fields’ performance. It allows a better use of the resources efforts in addressing performance gaps and optimization opportunities rather than being spent on multiple-source data gathering & visualization.
Examining Suicide Stigma and Suicide Literacy
Authors: Al Halyan Amal 
Published: November 2024

Abstract
According to the World Health Organization (WHO), around 800,000 individuals die from suicide; every 4 seconds, one person suicide. It is considered as a major public health issue by the WHO as it is the second leading cause of death among youth (15-29 years old) (WHO, 2019). WHO defines suicide as "the act of deliberately killing oneself" and self -harm as "an act with non-fatal outcome".
Recent study in Dubai showed that 78% of the suicide cases were reported among Indian nationals; and suicide rates were seven times higher in expatriate community than the nationals. Particular, among single employed expatriate males (Dervic et al. 2012).
The onset of mental health problems usually goes undetected, and as a consequence, one of the most outcomes of nontreatment or late detection of mental health issues is self-harm and/or suicide. One of the barriers for not seeking professional help is stigma towards mental illnesses. Knowledge about suicide, or suicide literacy, was another factor that was negatively contributing to the help seeking behavior. Evidence showed that lowering stigma by increasing suicide literacy has a positive impact on suicide prevention.
The WHO Mental Health Action Plan sat a target of lowering the incidence of suicide by at least 10% over an 8-year period (WHO, 2014). Despite the raising prevalence of suicide and its major impact on individuals, families and the communities, research on suicide in the Middle East is limited. Without proper understanding of the suicide behavior, the surround environment and analyzing the suicide decedent profiles; the public health prevention efforts would fail to target those at higher risk. Up to date, there are no literature that examines suicide in oil and gas industry. This is a narrative review paper on suicide, with great focus on literature from the Middle East. The aim of this paper is to have better understanding of suicide behavior in order to improve the help-seeking attitude among those who are at higher risk within the industry. Also, to provide the discerning theoretical knowledge to support awareness efforts to increase suicide literacy and decrease stigma.
Suicide is versatile and studying suicide to conclude "one-size-fits-all" recommendation is unworkable. The vast global literature concluded that suicide literacy is inversely linked to stigma and help-seeking behavior. Some geographical areas and professions showed higher number of suicide and work-related suicide in males than females. The nature of workplace culture and societal masculine norms may negatively influence men seeking help behavior. Substantial efforts are needed to build up a focused-prevention program that would effectively impact the suicide trajectory.
Methane Emission from Upstream Storage Tanks: Measurement and Quantification
Authors: Cao D. D. , Xue M. , Li X. C. , Cui X. Y. , Jiang D. P. 
Published: November 2024

Abstract
Climate change has emerged as one of the most severe challenges in the world. Greenhouse gas (GHG) emission was assumed to be the root cause. Carbon dioxide and methane are the most important GHG, while methane has a shorter atmospheric lifetime and higher global warming potential. Methane abatement was regarded as one of the most important measures to limit near-term global warming. Oil and gas (OG) production processes are key methane emissions sources, with storage tanks making significant contribution. Methane emission from upstream storage tanks in an OG field was confirmed using a portable flame ionization detector (FID) and measured with a full range sampler in China. The component and facility based emission characteristics were studied and compared. More than 70 storage tanks, including fixed roof tanks (FRT), internal floating roof tanks (IFRT) and external floating roof tanks (EFRT) distributed in production wells and processing plants, were measured. The leak detection results suggested nearly all tanks were suffering from methane emission problem and 147 leaking or emission points were identified with emission rate ranging from 0.0086×10-3 kg/h to 3.08 kg/h. The EFRT has higher facility-level emission rate than IFRT. In terms of FRT, the facility-level emission rate has a skewed distribution, ranging from 0.015 kg/h to 4.48 kg/h for working loss process. It was observed that 10 % tanks contribute 44.6 % of the total rate during working loss process and 13.3 % tanks making a 58.8 % share. The standing loss process follows similar law, with emission rate ranging from 0.042×10-3 kg/h to 0.088 kg/h. The total standing loss emission rate reaches 0.44 kg/h, with 22.6% tank having 64.5% contribution. The estimated average value of emission rate was 1.13 kg/h (EFRT), 0.05 kg/h (IFRT), 0.72 kg/h (FRT, working loss) and 0.014 kg/h (FRT, standing loss) respectively. The annual emission amount was estimated.
Leveraging Digital Twins for Enhanced Maintenance and Operations in Compression Stations
Authors: Machado R. , Rotheram S. , Soederberg P. 
Published: November 2024

Abstract
This paper focuses on the application of a digital twin at a large compression facility in the Middle East. The facility is currently under development, with the first of several compressor trains scheduled to begin operation in 2024.
The objectives of the digital twin application are early anomaly detection and improved reliability and maintenance through pre-empting failures and process upsets. It aims to revolutionize maintenance and operations by leveraging advanced data analytics and predictive modeling. The digital twin also supports virtual training, along with remote monitoring of the compression train -- enhancing safety and improving the productivity of onsite personnel.
By implementing a phased approach, the project ensures a seamless integration of core field data into a 3D virtual environment, supporting intelligent decision-making for operations and maintenance (O&M) activities in preparation for start-up. The main use cases of the digital twin include: Virtual training of operations and maintenance personnel on the compressor train while it is physically being built and commissioned at the facility.The ability to run diagnostics using predictive and prescriptive analytics from anywhere in the network (i.e., in a virtual environment or via augmented reality in the physical environment). The aim is to provide advanced notification of potential breakdowns and present personnel with the next steps for corrective action to mitigate risk and/or delay a process upset.Enhance training, diagnostics, and troubleshooting via remote collaboration with offsite experts in the customer's organization or with the compression train original equipment manufacturer (OEM) while in operation.Simulation and dynamic modeling for failure prediction and exploration of "what if" scenarios during operation.
Overall, the digital twin application is expected to deliver substantial improvements in reliability, efficiency, and safety.
Gaining Insight into Drilling Conditions in Challenging Extended-Reach Drilling Wells by Analyzing Downhole Mechanical and Dynamic Measurements
Authors: Weiguo Zhang , Deli Gao , Ke Ning , Chenghui Deng , De Yan , Tianyun Gao , Nan Huang , Deshmukh Vikrant , Wong Patrick 
Published: November 2024

Abstract
This paper presents a case study on the real-time monitoring of hole conditions in challenging extended reach drilling (ERD) wells using drilling dynamics data, including downhole mechanical measurements, pressure data, and logging data. This is of great value to the drilling team for a better understanding of the hole condition. This ultimately contributes to drilling safely and securely, avoiding surprises, and successfully delivering the well.
To effectively manage drilling operation risks, real-time monitoring of drilling conditions is crucial. Hole condition analysis can be subject to uncertainties when relying primarily on surface drilling parameters. To gain a more comprehensive understanding of drilling conditions, downhole mechanical measurements are invaluable for providing immediate and precise information about the Bottom Hole Assembly (BHA) and its surrounding environment. The methodology for evaluating drilling conditions was developed through the utilization of downhole mechanical measurements, such as axial loading, torsional loading, annulus pressure, and differential pressure, in conjunction with surface drilling parameters.
The pipe stuck rate is close to 30% in ERD operations for wells beyond 8000m in the offshore region of China. Downhole mechanical measurements (DMM) tool was utilized for drilling condition monitoring in the longest ERD well recently completed in China offshore. The well was drilled and cased successfully, setting several new records in China. These records include the longest production well, the longest 12-1/4 in open hole section of 5124 m, and the deepest 9-5/8 in casing setting depth at 8125m. Real-time analysis using downhole mechanical measurements and drilling dynamics data plays a crucial role in drilling surveillance and decision-making in this record-breaking ERD well. The abnormal drilling conditions such as weight hanging, string buckling, hard backreaming, inadequate hole cleaning, pack off, and mud losses, etc., were identified and properly addressed. In some conditions, standard industry practices did not work, so innovative practices were implemented to proceed based on the reliable real-time downhole information.
A comprehensive analysis of drilling mechanical measurements can significantly enhance the understanding of downhole conditions, narrow down hypotheses, and enable timely implementation of corresponding measures for complex downhole situations. The methodology can be referred to for other wells.
Investigating Surface Roughness Effects on Novel Indentation Testing of Drill Cuttings
Authors: Rached R. M. , Gramajo E. , AlDajani O. , Albahrani H. 
Published: November 2024

Abstract
Conventional methods to determine geomechanical properties (e.g., cores, drilling logs) are limited, costly, and usually confined to reservoir intervals. This study explores drill cuttings as an additional data source for geomechanical properties using micro-indentation testing. Specifically, the research focuses on the effect of surface roughness and aims to establish the minimum requirements for a surface finish that ensures consistent and reliable results. Our findings offer a systematic and cost-effective method to obtain geomechanical parameters, benefiting oil and gas projects and energy transition initiatives.
The approach involved extracting rock discs from eight different rock types: 2 shales, 3 carbonates, and 3 sandstones, and then polishing them using a series of various grit sandpapers, suspensions, and pastes. The surfaces of the polished rocks were scanned using optical profiling to quantify their roughness. Data preprocessing techniques were applied to remove outliers and correct surface level trends, and then root mean square (RMS) and average roughness (Ra) roughness parameters were calculated for each profile. Grid micro-indentation experiments were then conducted to measure the micro-indentation elastic modulus. The results were analyzed and compared for different surface finishes to identify the minimum roughness requirements for each rock type.
The study reveals that the sensitivity of instrumented micro-indentation testing to surface roughness is influenced by grain size and mineralogy. In most cases, rock surface polishing incrementally down to a P4000 grit sandpaper provides consistent microindentation results. By understanding the impact of surface roughness on geomechanical testing, this research contributes to improving the reliability and accuracy of geomechanical parameter determination and applies to most rock types and specifically, to drill cuttings. These insights have significant implications for the energy industry, presenting a cost-effective and accessible approach to obtain comprehensive geomechanical properties along the entire length of a well.
This study introduces new insights into the minimum surface finish requirements necessary for consistent and reliable microindentation results. By addressing the challenges in geomechanical testing, this research paves the way for a cost-effective approach to acquire geomechanical properties across entire wellbores.