bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enhancing Employee Morale by Providing Felxible Workweek Options: A Success Story in Sharjah
Authors: Shafique Fatima Muhammad , Al Haddi Mohammed 
Published: October 2022

Abstract
Since UAE has adopted a shorter workweek since the new year -2022, to align with global markets, many organizations have had to implement measures to adhere to this change. Sharjah National Oil Corporation has decided to provide their employees with multiples flexible weekend options to choose based on their convenience. A survey was conducted on the options provided to employees, for their feedback and effectiveness of this new change.
The employees had been provided with 3 flexible weekend options containing all details regarding working hours, work schedule, effect on leave entitlement etc. These options were circulated to all employees, and a meeting was conducted to address any questions on the options provided. Employees adopted the new options and a survey was conducted to evaluate the Effectiveness of the new weekend policy and its impact on business and team performance after the 3-month mark.
The survey questions were categorized based on employees personal, team and business perspectives.
Employees were sent a link to complete the survey online regarding their feedback and evaluation
A total of 86.5% of SNOC employees have participated in the survey, 13.5% of employees did not participate due to non-interest or absence from work. The results showed that 87.16% of employees are willing to stick with their current weekend selection for the remainder of 2022, 12.84% of employees wanted to change their option due to personal convenience and productivity levels.
Majority of employees have agreed that employee morale has increased and work-life balance has improved based on the new weekend policy change. 87% of employees have agreed that there has been no negative impact on their "personal" work productivity and 74% of employees have agreed there is no negative impact on "team" productivity due to the weekend change. Only 7% of employees agreed that the new weekend policy caused disruptions in day-to-day communications with colleagues and 6% agreed there was a negative effect on communication with vendors and other business entities.
Overall majority of employees have been positively impacted with the changes and agreed that the flexible options have provided them with more work life balance and has not impacted their work productivity.
However, employees have remained neutral on the increase of employee engagement since the policy update.
This paper helps to give better insight on how flexible weekend options can improve employees work life balance and productivity by giving them the flexibility to choose their own work schedule based on their convenience.
Flowlines Identification Using Cathodic Protection for Repair Activities
Authors: Gunasekaran Abirami Krishnan , Raju Vairamani 
Published: October 2022

Abstract
In ADNOC Onshore, during regular business operations, there are needs to maintain/replace/repair flow lines due to variety of reasons Rerouting of flow lines.Replacing flow lines due to excessive thinning of flow line due to corrosion.Third party damage.Replacing a section of flow line due to a leak
However, correctly identifying the flowline for maintenance / repair in the Fields is challenging because the target flowline is Same size and identical,Inaccessible due to sand dunes/under road crossing and isAmongst cluster of flowlines with no markersIn the same right of way
Time and time again, it has been noticed that the flow lines get intertwined like spaghetti. A typical scenario is provided in Figure -1. Therefore, it is very difficult to identify flow lines from one side of sand due to the other side.
Development of Inline Testing in Sour High Pressure Fields
Authors: Al-Busaidi Asaad , Al-Shabibi Ghusn , Al-Khanbashi Ali , Al-Jabri Rashid , Al-Mahrooqi Al Khattab , Al-Amri Fadhil , Chaari Rached , Al-Battashi Zakariya , Mihajlov Rodoljub , Al-Khusaibi Habib , Al-Hadhrami Abdullah 
Published: October 2022

Abstract
Newly drilled high-pressure sour wells require initial well testing before being hooked-up to a production facility. Mobile well test unit is sent to perforate, stimulate and test the new well potential. During operation, HC and H2S gases are flared to atmosphere. Innovative approach of Inline testing is invented by accelerating the well hookup and connecting the well to production station before well test unit intervention to avoid oil and gas flaring at well site.
After well pad release, Hookup process normally takes 3-4 months with good practices applied for acceleration. A mobile well testing is then sent to perforate, stimulate, clean out and test the well. After well clean up completed and ensuring clean HC fluids flowing, well flow is diverted to the flowline producing to the production station and testing using Well Test Unit separator with clear sequenced standard procedures followed up and integrated among Well Test Unit, Engineering and Production teams to ensure safe operation.
Inline testing approach was successfully implemented in two wells for the first time in high sour cluster fields in July-21 using CI methodologies and detailed risk assessments. A Flaring reduction of about 15% of total Oil flared in 2021 and 2% of gas during the two wells testing equivalent to more than 2,000 tons of CO2 emissions and a deferment reduction benefit of more than 1 mln USD. These results were achieved with good integration of different teams and stakeholders involved, clear operation procedures and live communications during the operation. Inline testing was then approved and planned for all coming new wells testing interventions (7-10 wells per year).
These successful two pilot trials open wider opportunities for extending inline testing for existing flowing wells when Well Test Unit intervention is required. More emission reduction is expected, and more production deferment will be reduced.
Repurposing Depleted Gas Fields into Potential Carbon Storage Sites - Case Study of Assessment and Screening Methodology
Authors: Haron Mohamed Fakhrullah , Ranjan Rakesh , Zulhaimi M. Jazlan , Muhammad Afandi Sarah , Narayanan Puveneshwari 
Published: October 2022

Abstract
As the world is moving towards low carbon future, it is vital to explore ways to reduce carbon emission and one of the way is carbon capture and storage. This paper discusses on the criteria and methods used in screening depleted gas fields in Peninsular Malaysia to be repurposed into potential carbon storage sites.
There are three main aspects to be considered for carbon storage sites which are containment, storage capacity and well integrity. Depleted gas fields are selected for potential carbon storage sites assessment due to its proven petroleum system which can retain hydrocarbon in its structure. This will reduce the uncertainty in terms of geological structure to store carbon downhole. Besides containment, storage capacity is another important aspect in screening for storage sites. After excluding fields with lower Gas Initially in Place (GIIP) which has lower potential storage capacity, screened fields are assessed for storage capacity by having high case and low case with different assumptions on percentage of gas Estimated Ultimate Recovery (EUR) replacement by carbon dioxide (CO2) and coupled with injectivity assessment via well model. The aspect of well integrity is also important when screening depleted gas fields as they could pose risks in terms of leak paths towards the surface. Both abandoned and producing wells are assessed in terms of cement integrity and material used in well construction.
A total of 151 Non-Associated Gas (NAG) in Peninsular Malaysia (PM) fields went through the first pass filters which includes removing fields with &lt;500 BSCF of GIIP to exclude fields with low storage capacity. Then pre-development fields are removed due to uncertainty on depletion timing. Further filter includes fields with significant EUR loss due to specified injection date because they are less likely to be commercial. From the first pass screening, 13 fields remained, and they are further assessed and ranked in terms of containment risks via geological complexity scoring, storage capacity and well integrity analysis.
This paper will provide valuable insights for operators looking to repurpose and retool depleted gas fields into potential carbon storage sites as the demand for low carbon future is increasing.
MethaneSAT - A New Tool Purpose-Built to Measure Oil and Gas Methane Emissions from Space
Authors: Hamburg Steven , Gautam Ritesh , Zavala-Araiza Daniel 
Published: October 2022

Abstract
MethaneSAT is a novel satellite mission designed to quantify anthropogenic methane emissions starting with the global oil and gas sector. MethaneSAT is scheduled for launch in 2023 and will provide quantitative data products on methane emission rates focusing on the majority of worldwide oil and gas production, with additional capacity to measure emissions from other sectors including agriculture. MethaneSAT combines three major observing capabilities into a single mission with broad area-level mapping (200 km wide swaths), high measurement precision of 3 parts per billion at 1-2 km2 footprints and high spatial resolution of 100 m × 400 m. These capabilities uniquely allow MethaneSAT to quantify total regional methane emissions, at the same time detecting high-emitting point sources and characterizing diffuse area sources. MethaneSAT is expected to fill significant data gaps in the understanding of the scale and magnitude of methane emissions regionally and globally. Owing to its unique observing capabilities, MethaneSAT will strengthen the emerging ecosystem of existing methane measuring satellites and will synergistically operate with other satellite missions. Operational data products quantifying methane emissions will be made freely available in the public domain via MethaneSAT's data platform, in order to help governments and industry reduce their emissions. In addition, MethaneSAT data will help global policy-relevant emissions database developmental efforts such as the International Methane Emissions Observatory as it integrates multi-scale emission datasets from various measurement platforms.
Industrial Internet of Things to Improve HSE Performance
Authors: Stinson Sean 
Published: October 2022

Abstract
Industrial businesses face increased pressure to drive operational excellence, and that includes keeping people safe and managing costs. Legal compliance is a requirement, and budget constraints are a reality. This paper examines how connected technology can help streamline safety processes and improve worksite efficiency. We discuss how data and real-time analytics from digitally connected devices using the Industrial Internet of Things (IIOT) can improve organizational productivity, compliance and safety performance including, most crucially, response time to life-threatening incidents.
On the ground studies with clients show an incident is resolved in the shortest period of time when using connected technology. Using traditional methods, we found an incident response can take up to 3 and a half hours which, when dealing with toxic gas exposure for example, only leads to the recovery of a body. With connected technology, the worker can be rescued in less than five minutes and their life saved. Connected technology also supports organizational environmental, social and governance (ESG) efforts by protecting people and communities with capabilities that allow for plume dispersion modeling that prevent downstream impact and location technology to easily find and retrieve lost devices.
Overall, our research determined that a more digital environment means enhanced competitiveness, compliance and performance by delivering:
Higher quality and faster decisions Increased transparency, collaboration and efficiency Better outcomes, including driving to net zero and saving lives.
Distributed Temperature Sensing (DTS): An Attempt to Compare Multivendor Data Acquisition and Interpretation Process for Possible Standardization at Field A
Authors: Rachapudi Venkata Subba Ramarao , Patel Dipen , Al Dhuhoori Moza Saeed Abdulla , Albarracin Ruben Dario , Iqbal Javid Khalid Javid , Al Jasmi Sami , Konkati Sarath , Al Mansi Mohammad Kamel , Wak wak Amr , Titov Boris , Sajjad Fahad 
Published: October 2022

Abstract
In Oil and gas industry, demand for DTS (distributed temperature sensing) completions installation is rapidly increasing in recent times. Currently multiple vendors are installing the DTS completions at field A for real-time water flood conformance monitoring and to meet target production rate. This paper discusses about the insights of data acquisition process and interpretation approaches to generate a standard operating procedure specific to Field A.
DTS Completions are being installed in field A for few years, and they will be key in generating the optimum water injection profiles, proactive water flooding surveillance, injection/ production optimization and better reservoir management. However, the data acquisition, conditioning and interpretation is vendor specific. Moreover, the interpretation is influenced by the procedure followed for data collection, warm back period, the fluid at down hole, reservoir rock properties as well as the models being used for interpretation. In view of this multivendor installations available at field A, there is a need to standardize the data acquisition & interpretation process that will allow all reservoir and petroleum engineers in the field to analyze the DTS profiles regardless of the type of vendor DTS completion installations.
Field A has 13 DTS Completions installed in multiple reservoirs from three different vendors, and the injection profiles for these wells are being generated. This paper summarizes the influence of key parameters and/or assumptions that play a major role on the interpretation results and their variability during data collection stage. Further, the comparison of the injection profile generated by DTS with mechanical PLT will be discussed, and the use of PLT data for fine-tuning the interpretation model.
In addition, time-lapse injection profile generated at a specific well will be compared to understand the reasons for variation of it over a period. Additionally, the recommendations for improving/ optimizing the injection profile in few cases will be discussed including stimulations for better conformance and injection rate adjustments. In the conclusion, the proposed unified procedure covering data acquisition, format, storage, and standardized interpretation approach will be discussed.
This is an attempt to standardize the DTS data collection and to unify the interpretation process among the multiple vendors in a specific Field A.
Private 5G Practice in Oil and Gas Industry
Authors: Alanazi Abdullah Mohammed , Almutairi Naif Radhyan , Aseery Abdullah Ahmed , Al Buraiky Salah M.S , Rafie Amani M. , Alrumaih Abdullah Abdulrahman 
Published: October 2022

Abstract
The Kingdom of Saudi Arabia has taken active steps to adopt cutting-edge technologies such as artificial intelligence (AI), Cloud, 5G, 3D printing, robotics and unmanned aerial vehicles (UAVs) to drive domestic value creation, improve localization, and maximize long-term economic growth and diversification. This is accelerating the digital transformation across many sectors such as energy, mining and logistics, tourism and culture and education, and advancing their business operation activities. Saudi Aramco, a world leader in hydrocarbons exploration, production, refining, distribution and marketing, and one of the world's largest exporters of crude oil and natural gas liquids, has always been at the forefront of technologies and continuously invested in digital transformation to maintain our competitiveness. We have realized that 5G plays a pivotal role in bringing all emerging technologies such as advanced analytics, intelligent sensing, mobility, and robotics as part of the Industrial Revolution 4.0 synergy. In January 2021, Saudi Aramco, stc, and Huawei signed a MoU (Memorandum of Understanding) to launch a joint innovation program for 5G and explore 5G assisted technologies for specific oil and gas (O&G) industry applications. Private 5G is a promised technology to enable digital transformation at Oil and Gas Facilities due to its unique capabilities. The deployment options for private 5G at enterprise, similar to Saudi Aramco case, could be Leased from Service Provider, Fully Owned by the Enterprise, or Hybrid Model. This report is focusing on the implementation of the third deployment model; Hybrid model, Network-Shared RAN & Control Plane, with the service provider, that was implemented in collaborations with STC and their network provider Huawei at Abqaiq plant. Private 5G deployment at Saudi Aramco has introduced eight (8) use cases related to safety, security, and plant operation. The use cases were selected collectively by several organizations within Saudi Aramco including Industrial Security, loss prevention, and Abqaiq plant Operations. The selected use cases end-user components are novel and had been co-invented and developed jointly with different partners to accelerate the maturity of industrial 5G ecosystem. Based on the pilot results, Saudi Aramco is planning to expand the 5G deployment through Hybrid model capitalizing on Shared Radio Access Network (RAN) to achieve design simplicity, scalability, and optimized cost.
A Holistic Approach to the Development of Digital Twin Advisor for Upstream Production Process
Authors: Mohd Sahak Muhammad Zakwan , Myo Thant Maung Maung , Tumian Afidalina , Harun Zalina , Castillano Eugene , Chee Su Be , Tan Kathryn 
Published: October 2022

Abstract
From upstream production process/operation perspectives, adoption of digital twin linked with real-time data for operational monitoring and advisory can assist in early determination of abnormalities that can result in potential failure events, based on deviation from the operating setpoints and limits. In addition, prediction capability of the digital twin model can assist in prevention of unplanned production deferment and proper maintenance planning. The digital twin model can also recommend optimum operating points based on changes in the system as operational guidance to further improve and optimize the system performance. This paper outlines the holistic approach taken for the development of digital twin-based advisory system for upstream process monitoring and optimization.
Based on a case study, a step-by-step approach for the development of a digital twin model for fuel gas system is being described. This technology combines various aspect of process and operation models. The Integrated Operating Limit Model acts as the first layer of digital twin model, which provides the operators with a quick assessment based on the visualization or representation of the real time operating points versus the operating set points and limits defined in the system. Process simulation model predicts other operating parameters not covered by the existing instrumentations, serving as virtual analysers, providing near real-time equipment and unit performance. Data driven model can be used for prediction, optimization and anomaly detection, and based on the prediction model development, comparison between linear regression (LR) versus decision forest-based model showed LR to be more reliable approach based on the validation against the actual operation data especially during upset condition (R2 of 0.9 vs 0.27). A graphical user interface was also developed to translate and summarize the model outputs into a clear visualization to be used by the operation team as advisory and surveillance tool. Combination of these models’ outputs would allow operator to essentially screen for potential process upset and apply further optimization based on the recommendation provided.
Experimental Investigation of High Pressure, High Temperature (HPHT) Adsorption of Methane and Natural Gas on Shale Gas Samples
Authors: Tsau Jyun-Syung , Barati Reza Ghahfarokhi , Zaghloul Jose , Alhajeri Mubarak M. , Bradford Kyle , Nicoud Brian 
Published: October 2022

Abstract
The adsorption capacity of shale is commonly measured in the laboratory under low pressures. At low pressures, the excess adsorption capacity is approximately equal to the absolute adsorption capacity. Under high pressure, however, the excess adsorption is far less than the absolute adsorption capacity. The objective of this paper is to extend the adsorption measurements to a high temperature of 275 °F and pressure up to 9000 psi. Under such a HPHT, the adsorption curve shows a characteristic of supercritical high-pressure isotherm in which a critical desorption pressure can be identified. The adsorption isotherm under HPHT facilitates a better assessment of gas reserves for an effective assessment of shale gas reservoirs. The adsorption is measured based on a volumetric method. An in-house built setup was constructed to conduct the adsorption measurement at HPHT. The volume of sample cell and reference cell was calibrated with non-adsorbed Helium gas. Methane and field produced natural gas were used as adsorbate while the shale samples at different depth from a Gulf Coast organic shale were used as adsorbent. Excess adsorption measurements were carried out at reservoir temperature of 275 °F with 500 psi incremental pressure at a time until the pressure reaches 9000 psi. The absolute adsorption was calculated from the excess adsorption accordingly.
The excess adsorption isotherm shows a typical supercritical fluid adsorption behavior. The adsorption increases with pressure, reaches a peak point at which pressure is defined as critical desorption pressure (CDP), and then decreases at pressures above CDP. The CDP of methane is higher than that of natural gas while methane is a majority of its component. The maximum amount of adsorption determined from the measurement varies from 203 to 213 SCF/ton. The Langmuir model does a good job predicting the absolute methane adsorption but fails to properly describe the adsorption behavior of natural gas at high pressure. This work presents a HPHT adsorption measurement at pressures and temperatures typically seen in deep shale gas reservoirs. The supercritical fluid adsorption behavior presented may assist the assessment of gas reserve and development of gas production.