bluuebunny/crossref_metadata_2025 huggingface dataset:
Relationship between the incidence of patient falls and safety culture in a healthcare organization.
Authors:   JSC «Medicina», Roytberg G. E. ,   Pirogov Russian National Research Medical University, Vachnadze D. I. ,   JSC «Medicina»,   Moscow Institute for Healthcare Organisation and Medical Management, Kondratova N. V. ,   JSC «Medicina»,   Pirogov Russian National Research Medical University, Galanina E. V. ,   JSC «Medicina»
Published: October 2024

The problem of patient falls in healthcare organizations is a pressing concern for modern healthcare. Falls can lead to serious consequences, including significant limitations in physical activity, the development of anxiety disorders, and depression. Additionally, fall-related injuries are associated with high costs for treatment and rehabilitation. Special comprehensive programs are implemented in healthcare organizations to prevent falls, but the success of their implementation largely depends on the level of safety culture among healthcare personnel. The aim of this study is to investigate the relationship between the level of safety culture among healthcare personnel and the frequency of patient falls. Methods. The study was conducted in the multidisciplinary clinic JSC «Medicina» in Moscow from 2014 to 2020. The safety culture was assessed using the SOPS Hospital Survey 1.0 (HSPSC). The frequency of falls was evaluated based on online forms filled out by staff. Results. The study assessed the dynamics of the fall frequency per 1,000 bed-days in the hospital. Falls were categorized according to the severity of associated injuries. A correlation was found between the fall frequency and safety culture composites, such as «teamwork» –0.826 (p=0.022), «learning from errors» –0.747 (p=0.049), «executive actions in support of patient safety» –0.760 (p=0.047), «overall impression on patient safety» –0.821 (p=0.024), «frequency of reported incidents» 0.782 (p=0.038), «openness of communication» –0.846 (p=0.017), «unit collaboration» –0.867 (p=0.012), «shift handoffs and patient transfers» –0.791 (p=0.034), «non-punitive response to errors» 0.838 (p=0.019), and «average level of safety culture across all composites» –0.809 (p=0.027) (table 1). Conclusion. The study confirms the importance of assessing safety culture as part of a comprehensive approach to prevent patient falls in hospitals. The level of safety culture among healthcare personnel is inversely correlated with the frequency of patient falls. An increase in the level of safety culture is associated with a decrease in fall frequency and a reduction in the number of associated injuries. Additionally, the level of safety culture may potentially serve as an integral indicator of the effectiveness of programs aimed at preventing adverse events related to medical care. The study’s findings are relevant for a wide range of readers interested in issues related to healthcare safety.
Revolutionizing Oil Recovery and Separation Efficiency in Zaafarana Field: A Nano-Technology Approach Validated by Lab-Simulated Experiments and Simulation Modeling
Authors: Alfy Shady. H.
Published: October 2024

Zaafarana Field, managed by Cheiron Petroleum Corporation, emerges as one of the most important offshore assets, located 90 km south of Suez City within the Gulf of Suez. It comprises two reservoirs, Kareem and Rudeis, which have collectively sustained significant oil production over 26 years. However, the Rudeis reservoir presents distinct challenges with its high residual oil saturation and robust water drive mechanism, resulting in a stable 90% water cut across the majority of wells, limiting oil recovery potential.

In response to these challenges, a groundbreaking nano-technology product was introduced to modify wettability via structural disjoining pressure mechanisms, showing immense promise in addressing recovery constraints. By incorporating non-toxic, non-hazardous, and cost-effective nano-particles into the reservoir matrix, remarkable advancements have been observed in lab-simulated experiments.

Lab experiments with Zaafarana core plugs and reservoir fluids revealed that the introduction of nano-particles significantly altered wettability, reducing residual oil saturation (SOR) and enhancing interfacial tension between oil and water. Notably, the time required for oil-water separation plummeted from half an hour to a mere one minute, underscoring the technology's potential to revolutionize separation processes.

To quantify the technology's impact and present tangible evidence to management, extensive reservoir simulation modeling efforts were undertaken. These simulations, rooted in operational excellence and company SOPs, elucidated the economic implications and potential production enhancements achievable through this innovative approach. By modifying the simulation model to reflect the introduction of nanoparticles and altering relative permeability curves to simulate invasion scenarios, remarkable gains were projected.

This comprehensive approach, integrating lab-simulated experiments and validated simulation modeling, underscores Zaafarana Field's commitment to operational excellence and innovation. By leveraging the benefits of nanotechnology, the field stands poised to optimize oil recovery, minimize water cut, and enhance separation processes, all while adhering to stringent environmental standards and maximizing cost-efficiency.
SCADA Based Pipelines Cathodic Protection Systems Remote Monitoring Project
Authors: Hussein A. , Abd Alhameed H.
Published: October 2024

This paper presents a remote monitoring system for pipeline cathodic protection using Supervisory Control and Data Acquisition (SCADA) technology, aimed at enhancing the efficiency of corrosion prevention. By enabling real-time monitoring of cathodic protection status, operators can facilitate timely interventions and maintain pipeline integrity more effectively.

The proposed approach integrates SCADA technology with pipeline cathodic protection systems for real-time data collection and monitoring. Key components include transmitters that gather electrochemical data, such as Direct Current (DC) and Alternating Current (AC) potential measurements, from the pipeline. A central SCADA system receives and visualizes this data for analysis. Operators can monitor cathodic protection levels, receive alerts for abnormalities, and execute remote controls. Additionally, the system interfaces with the SAP MII system to enhance data visibility, automate maintenance notifications, and improve overall operational efficiency.

The project began in 2016 with prototype installations in GASCO, using one gas pipeline as an experimental site. In 2022, the project was included in GASCO's planned projects for implementation across the national natural gas network. The objective is to transmit cathodic protection signals to more than 60 gas pipelines, encompassing 120 sites nationwide. Implementation has been completed at several sites, leading to the discovery and repair of emergency faults in cathodic protection transformers within 24 hours. The SCADA-based cathodic protection monitoring system has shown promising results in enhancing corrosion prevention efficiency. Real-time monitoring capabilities allow for prompt detection and rectification of issues, significantly reducing maintenance costs and improving pipeline safety and reliability.

Significantly, the system's integration with SAP Manufacturing Integration and Intelligence (MII) enhances operational transparency and facilitates predictive maintenance, ensuring pipeline integrity. This proactive approach contributes to environmental protection and safety standards in pipeline substance transportation.

Conclusively, this paper introduces a novel integration of SCADA technology with pipeline cathodic protection systems, providing significant advancements in real-time monitoring and management capabilities. The addition of SAP MII integration presents a unique approach that enhances operational efficiency and data utilization, contributing new insights and methods to the petroleum industry's existing body of literature. The findings indicate that implementing SCADA-based cathodic protection monitoring systems can substantially improve the efficiency, safety, and reliability of pipeline operations.
Reviving Production from Bypassed Oil in Deep Gulf of Suez Reservoirs, Case Study from GUPCO
Authors: El-Ghalid M. , Aboelhassan M. G. , Abdelhamid K. , Ibrahim M. , Mousa H. , Abd Allah A.
Published: October 2024

This case study presents a success story of a new oil well in a mature field re-accessing and developing Nubia-M1 member in GS172-Block of the Gulf of Suez (GOS) based on the concept of segregation and water coning after it was shut in for more than 16 years.

An extensive, multi-discipline study was conducted in 2019 on the GS172 block in the GOS, targeting Nubia reservoir, the study aim was to fine tune the location of a new well that will be sidetracked from an old well after failure to work-over that old well in 2016. Furthermore, the team studied water movement in the deeper member Nubia M1 utilizing analytical approaches to understand fluid movement within the reservoir to identify areas of bypassed oil.

The analytical work suggested a potential for bypassed oil accumulation in Nubia M1 member after it has been isolated in all wells. The study proved that the increase in water cut in Nubia M1 in many wells resulted from water coning rather than Oil Water Contact (OWC) rise. Besides, the high vertical permeability along with more than 16 years of shut-in there was an assurance of the segregation concept. The study also revealed a new location slightly up-dip from the old well to develop the remaining reserves in Nubia TZ member as the primary target of the new well. The original well was planned to restore production from Nubia TZ member after failure to work-over the old well to maximize oil production from the field. The modified plan was to deepen the well to Nubia-M1 member even if an OWC was seen in the TZ or MN members to prove that there was remaining bypassed oil in the M1 member in the old well.

The well was drilled and penetrated the deeper Nubia-M1 successfully and proved the bypassed oil from the OHL and started production from the M1 with 1500 bopd.

Another success story in the GOS that highlights the teams’ amazing collaboration and dedication. It is a motivational case study that highlights the team's extraordinary ability to hunt the opportunities to maximize oil from a mature brownfield in the GOS by the Reestablishment of the production from bypassed oil accumulation in deep reservoirs.
A Novel Method of Predicting Fractured Tight Sandstone Reservoir Permeability from Electrical Image Logging
Authors: Li Gaoren , Yan Ronghui , Liu Tianding , Sun Xiaoping , Wang Peixian , Xiao Liang
Published: October 2024

Permeability is an important input parameter in Tight reservoir characterization and evaluation, precisely predicting formation permeability is indispensable. However, permeability prediction faces great challenge in tight sandstone reservoirs, empirical statistical methods, and nuclear magnetic resonance (NMR) based models lose their role due to complicated pore structure and the effect of methane gas (CH4) or hydrocarbon to NMR responses. In addition, fractures also play important role in improving tight reservoir permeability, whereas current logging responses cannot be used to characterize this improvement besides electrical image logging. In this study, to quantitatively characterize the improvement of fractures to filtration capacity in tight sandstone reservoir and accurately predict permeability, the Triassic Chang 63 Member of Jiyuan Region, Northwestern Ordos Basin is used as an example, a novel model of predicting permeability from electrical image logging is raised. In this model, the porosity frequency spectra are first extracted to characterize the pore structure of fractured tight sandstones. Afterwards, two parameters, which are defined as the logarithmic geometric mean value (φmv) and the golden section point variance (σg) of porosity frequency spectrum, are extracted to characterize the contribution of fractures to permeability. Comparing with the shape of porosity frequency spectrum, permeability φmv and σg, the quality of our target fractured tight sandstone reservoirs is quantified, and relationships among permeability, φmv and σg are established. High-quality reservoirs exhibit wide porosity frequency spectrum, high values of φmv and σg, and vice versa. Three parameters, which are formation total porosity, φmv and σg, are chosen to establish a novel fractured tight sandstone reservoir permeability prediction model. The involved input parameters in this model are calibrated by using the routine experiments of 35 core samples. Finally, we apply this model into field applications to consecutively calculate permeability in the intervals with which electrical image logging is acquired. Comparison of predicting permeability with core derived results illustrate that our raised model is usable in the Chang 63 Member of Jiyuan Region. The average relative errors between these two kinds of permeabilities is only 16.54% in 12 wells. This research gives a novel technique of calculating permeability in fractured tight reservoirs. It can avoid the effect of CH4 or hydrocarbon on conventional and NMR logging responses, and will play a great important role in unconventional reservoirs permeability prediction and formation characterization.
Revealing of Deep Paleozoic Reservoir Using Seismic Attributes to Detect the Distribution Foot Print Effect on Modern Broadband Seismic Data, A Case Study from the IO Gas Field, Shushan Basin, North Western Desert, Egypt
Authors: Sobhy Mohamed , Elsayed Khaled , Eid Emad , Podboronov Dmitry , Hassan Mahmoud , Mohamed Hazem
Published: October 2024

Deep sand distributions are a vital component of reservoir characterization and the generation of successful reservoir prediction. Through the integration of selected seismic attributes using broadband seismic data. The reservoir distributions and architectures are accurately delineate the deep Paleozoic reservoir in IO gas field. Seismic interpretation on broadband data helping in making 3D structural modeling generate a regionally accurate image of the subsurface structures at low relief three way closure on the foot wall down thrown block. Seismic attributes like (second derivative and RMS Amplitude) could indicate that Paleozoic reservoir is characterize by the presence of discrete sand body (sand-filled channel). Seismic attribute provided an extensive vertical and lateral information set for the reservoir heterogeneity between wells; it was utilized as the information requirement in prediction of lithofacies distribution. The lithofacies obtained from integrating seismic attributes from seismic broadband data are calibrated with facies identified using well logs. The lithofacies model derived from this integrated approach provides an additional geologic insight into the stratigraphic architecture and reservoir distribution and lessens exploration/development risk in the IO gas field. The IO discovery gives us a good justification to follow this well with MAAT N-1X ST3 well to reveal the sand distribution in this area (recent extraordinary success gas/condensate discovery) and it will open new opportunities that have similar phenomena. The resulting workflow is an effective tool for highlighting potential areas of better quality reservoir development, thereby demonstrating the value of this integrated approach
Minimizing Gas Flaring During Plant Depressurization
Authors: Asal M. Abdelraof , Bishr Hassan , Aboul-Fetouh Mostafa E. , Aboul-Fotouh Tarek M. , Gomaa Sayed , Khaled Mahmoud S.
Published: October 2024

During plant depressurization, valuable gases are burned through a flare system in preparation for maintenance. Plant modifications (such as transferring high-pressure gases to the fuel gas system using pressure regulators) should be conducted to minimize the flared gases. Liquified petroleum gas (LPG) storage tanks may also be depressurized through gas compressors to move the gas from tank to tank to reduce the flaring of LPG products. The plant piping and instrumentation diagram (P&ID) study is crucial for allocating the gas transfer ways from high-pressure to low-pressure sections like fuel gas package and building a low-emission system which will be used before plant depressurization for the planned maintenance activity. This paper suggests a new technique to minimize gas flaring during planned plant maintenance. The plant P&ID is studied in deep through a multidiscipline team to ensure plant safety during depressurizing and to minimize the total depressurizing time as much as possible. Adding some small connections with positive isolation is used to connect high-pressure and low-pressure sections which will be used only during plant depressurization and positively isolated during plant depressurizing.

The results show that a total of 175 tons from 4 tanks and 3 small pullet tanks was saved using a vapor recovery unit (VRU) to transfer the LPG vapor from the tank under maintenance to the running tanks.

In addition, 1.5 MMSCFD of mixed gases from the onshore plant was saved by applying the staged depressurizing technique. The suggested modifications may be applied to other gas plants to reduce emissions and save the environment.
Maximize Oil Production from Mature Wells by Using ESP & HJP Combined System
Authors: Yasser Mohamed D.
Published: October 2024

ESP – HJP combined technique is presented that utilizes ESP and HJP systems in series by dividing the total dynamic head (TDH) into two sections. The first section of TDH (well side section) is accomplished by installation a smaller fixed speed ESP whereas; the second section of TDH (wellhead side) is completed by incorporation HJP system. Results are compared to previously install conventional ESP system for the TDH. Typical ESP-HJP combined system is illustrated in Fig. 1

For mature wells, the reservoir pressure declines and so does the bottom hole flowing pressure. Therefore, the reservoir pressure cannot be able to lift the produced fluid to the surface at economical rates. Artificial lift system should be implemented as a primary recovery method to reduce the bottom hole flowing pressure. Consequently, oil production is increased to the desired limits.

ESP-HJP combined system employs ESP system of a smaller electric motor integrated with a fewer stages centrifugal pump. The centrifugal pump is sufficient to lift the fluid to about two thirds of the total dynamic head. The artificial lift system is completed by incorporating HJP system as shown in Fig. 2
Advanced Multifunction Autonomous Robot for Gas Detection
Authors: Abd Elgwwad Said Mohamed
Published: October 2024

"A blend of engineering & management skills"

One of the most affected definitions of process safety management (P.S.M) which focused on preventing major incidents within high hazardous industries (e.g., catastrophic accidents, near misses, fires, explosion, toxic gas releases etc.) associated with loss of containment of energy or dangerous substances such as chemical & petroleum products [EL adopted from the ccps/AICHE].

Many incidents are due to inadequate leadership & poor organizational structure while (P.S.M) still focused on physical control, design improvements & engineering solutions. software engineering became one of the engineering solutions represented in embedded system as a good fit, when merging the principles of P.S.M with engineering software a great result will occur to keep the safe operation along time with low frequency & high severity risks.

Fusion product is a robot intenerated with microcontroller come with multifunction purposes helping in data logging, analysis & reporting to identify potential hazardous & improve safety protocols.

Abstract here is to develop prepared previously autonomous car microcontroller-based with features allow employees to detect, monitor gas leakage serving with this the P.S.M roles especially in oil & gas field, chemical stores & other industries threatening to loss of containment (e.g. liquid petroleum gas (LPG), smoke, other unwanted flammable or toxic gases).
Identifying Wettability Preference of Dolomite Rock Based on Pore/ Grain Contact Angle Using the SEM-BSE Technique
Authors: Al-Ajaj H. , Al-Bazzaz W. H. , Flori R. E. , Ibrahim D. S. , Alsayegh S. , AlMubarak H.
Published: October 2024

An accurate technique was used to evaluate the wettability preference of Dolomite fresh core plugs from a native Kuwaiti tight carbonate reservoir. The evaluation was based on the classification of the rock wettability through the measurements of contact angles at pore area and pore/ grain-wall boundary system by 2D technology digitally captured images of available fresh cores using Scattered Electron Microscope (SEM) with Backscattered Electron (BSE) detector segmentations. The generated data were used to estimate the wettability distribution through the investigation of information at three different magnifications of X40 (mm), X400 (μm), and X4000 (nm), where big data statistical wettability contact angles at the pore/ grain boundary distinct morphological features were closely examined. The pore counting method and big data were used to count all pores and pore/ grain wettability contact angle (θ°) measurements. The 2D contact angle classifications were set equally, spanned between 0° to 360° degrees over ten clusters, and the group class average was technically calculated. The Al-Bazzaz classification has been relied upon to evaluate the wettability of the dolomite reservoir rocks and to provide suggestions for optimal oil recovery methods. The degree of wettability preference of the dolomite reservoir rocks has been thoroughly examined, and a detailed evaluation of the rock's preference for wettability in each contact angle cluster has been performed. The results show that the overall pore/ grain-wall wettability preference is 78.85% towards general water wet, and the remaining wettability preference tends toward 21.15% for general oil wet. With its 78.85% preference towards general water wet, this dolomite rock system is an excellent candidate for secondary water displacement developments, offering significant practical implications for petroleum engineering and geology.
Influence of Potassium Salts on Adsorption and Surface Hydration Inhibition of Hexane-1,6-Diamine Clay Mineral Inhibitor: A Molecular Dynamics Study
Authors: Kiiza Justine , Xu Jiafang , Camara Moussa , Kitira Kelvin-Elly Gamma , Chen Jie , Wang Xiaohui , Musungayi Georges Matamba
Published: October 2024

Most shale formations, contain a large amount of expansive sodium montmorillonite (Na-Mnt), have high water adsorption, and hydration swelling, causing unstable wellbore wall, resulting from formation shrinkage, sticking, balling, time-wasting, and well collapse in extreme cases causing complex downhole accidents, and high costs. Polyamines like hexane-1, 6-diamine (HEDA), are shale inhibitors in shallow drilling. Inorganic, and organic K-salts can improve the inhibitory performance of polyamine inhibitors. Molecular dynamics (MD) simulations were applied to investigate K-salts' influence on the inhibition mechanism of HEDA to the Na-Mnt. The adsorption configuration is mainly by terminal amine groups with a flat-lying alkyl hydrophobic chain. Interaction with clay surface decreased the H2O-clay H-bonds, electrostatic, and van der Waals interactions, neutralised Mnt surface negative charge, reducing its surface hydration. HCO2K significantly improved the inhibition ability, and coordination of interlayer ions with H2O as they were replaced by K+, and H2O-HCOO- coordination reduced H2O-Mnt interactions, mobility capability of H2O molecules was significantly decreased. Its maximum concentration noted in this study is 1.65 wt.%. While KCl showed little ability, it also caused more hydration with time. HCO2K could be an alternative for offshore drilling instead of toxic KCl. This study provides a theoretical explanation for the inhibition mechanism and adsorption characteristics of HEDA inhibitor on Na-Mnt surfaces in the presence of K+-salts and may provide more insight into the evaluation, selection, and molecular design of new clay-swelling high-performance WBDF systems used in oil and gas complex offshore drilling well sections.
Fully Automated Wellhead Choke & Flow Line Calibration on a Daily Basis for a Complex Surface Network with Over 1200 Active Producers: A KOC North Kuwait Case Study
Authors: Gabriel Irinel , Mohamed Walid , Rashedi Hamad Salem Al , Roopal Allen , Saleh Nada
Published: October 2024

A giant onshore KOC oil asset has a complex surface network with hundreds of jump-overs, several manifolds, trunk lines & thousands of flow lines. The goal of the asset is to identify bottlenecks that is impeding production, determine hydraulic health of pipelines and identify optimization opportunities. Only way to reach the mandate set by the asset is to have a calibrated surface network model on a daily basis which then can be used to confidently identify issues in the network.

Wellhead Chokes for individual wells are calibrated using a dedicated workflow called as Automatic Choke Calibration (ACC) workflow. ACC workflow selects only wells which have valid IPR/VLP files. Eight simulation runs are performed by varying wellhead choke discharge co-efficient (CD). Iterations are performed to calculate exact CD which will match pressure delta observed in the test across the choke. If deviation is within +/-5% then choke is flagged as calibrated. Automatic Network Model Calibration (ANMC) workflow is used for calibrating entire surface network starting after the wellhead choke till GC slot. Workflow identifies wells which have valid IPR/VLP, chokes are calibrated, have valid connection length, real time wellhead pressure (WHP), Flowline pressure (FLP) & artificial parameters. Averaged (24 hours, 5:00 AM to 5:00 AM) real time pressure data are updated for pipelines which will be undergoing calibration. Pipeline connections are calibrated by adjusting friction factor multiplier using simulating annealing algorithm to match the observed real time pressure data. For pipelines which are successfully calibrated, their friction factor multiplier values are stored in the database. Finally, model is updated by incorporating friction factor multiplier value identified in the calibration process. With a calibrated model, engineers have greater trust on the virtual rates reported by the simulation tool for individual wells & pipelines. Friction factor multiplier reported by the workflow has given valuable insights into the hydraulic health of the pipelines enabling engineers to take preventive actions effectively. Calibrated model is used by another workflow to identify changes which have to be performed in terms of choke and artificial lift parameter to maximize oil production.

This paper describes a pioneering new way of developing an integrated & automated workflow for calibrating choke and surface network on a daily basis instead of traditional way where calibration is performed less often which has major implications on the recommendations provided for the day-to-day operations of the asset.
Consequence Analysis of High-Pressure Natural Gas Pipelines to Determine the Safe Zones Around the Pipelines by Using PHAST
Authors: EL-Kanishy A.
Published: October 2024

Natural gas pipelines are essential for energy, but their failures can result in severe consequences. Egypt has established measures that include location classification for pipeline safety design and operation. Additionally, safe separation distances from communities are defined based on risk assessment principles. Nonetheless, a standardized method for determining these distances is lacking.

This research introduces a methodology employing PHAST consequence modelling to ascertain safe separation distances, replacing the Fixed Distance/Rule-Based approach. Event Tree Analysis evaluates potential hazards from pipeline ruptures, such as dispersion and explosions. PHAST simulates these hazards, delineating zones for gas dispersion, thermal radiation, and overpressure. It models full-bore ruptures of varying pipeline sizes and pressures under different soil conditions. The modelling identifies safe distances for specific gas concentration, thermal radiation, and overpressure metrics. Results are illustrated through tables and graphs correlating safe distances with pipeline specifications.

The PHAST modelling indicates that safe separation distances are directly proportional to pipeline size and pressure. Flammable gas dispersion is notably longer in sandy soil than in mixed soil. Stable weather conditions (2/F) produce larger dispersion areas but reduced thermal radiation and overpressure distances compared to neutral conditions (5/D). When compared to UKOPA and IGEM standards, PHAST modelling often predicts equal or greater safe distances. Methodological validation occurred by aligning the PHAST simulation of the 2021 Raven pipeline incident with observed flammable gas zones.

Recommendations emphasize integrating safe distance findings into Egyptian legislation, exploring other hazardous materials, and mitigating ignition sources near pipelines due to flammable zone risks. The PHAST model serves as an effective tool for determining safe separation distances for natural gas pipelines, accounting for various operational factors.
Comparative Study of Hydrogen Production from Organic Waste Fermentation and by Electrolysis to Achieve Sustainability and Decarbonization
Authors: Boshnak Eman. Bedair. Abdelbaset.
Published: October 2024

Hydrogen has a vital role in attaining a sustainable and carbon-free future. Especially, when hydrogen is generated from renewable energy resources, hydrogen acts as an environmentally friendly source. this study compares the generation of hydrogen from the fermentation of organic wastes and water electrolysis. This study aims to collect data to help decision-makers make their decision according to effectiveness, cost-effectiveness, and sustainability.

Hydrogen power has many advantages, such as sustainability and clean energy, and can be used in industry, power generation, and transportation. Reducing the carbon footprint of hydrogen production requires generating hydrogen from renewable energy resources.

Fermentation of organic wastes produces hydrogen and other products during anaerobic digestion, which requires a breakdown of organic material by microorganisms in anaerobic conditions. This technique not only produces hydrogen but also aids in the management of organic wastes. On the other hand, water electrolysis is an electrochemical process that consumes electricity to split water into hydrogen and oxygen. If the source of the electricity is renewable the generated hydrogen is called green hydrogen, which is completely carbon-free.
Enhanced Integration to Characterize Heavy Oil in Complex Environment
Authors: Mattar Tariq , Ahmad Hamza , Sultan Gamal , Ramadan Moad , Maguri Ahd , Badr Ashraf , Masoud Ayman , Salih Abdelmalek
Published: October 2024

Heavy Oil Exploration is one of the great challenges faced in upper Ordovician in Murzuq basin due to the geological & petrophysical complexity. Few wells were explored earlier & resulted in water production. Leaving high uncertainty behind.

Hydrocarbon exploration in the Upper Ordovician, Mamuniyat Formation in Murzuq Basin is known to be challenging, being a product of fluvioglacial and glaciomarine processes, it is characterized by episodes of erosion and deposition. This resulted in stratigraphic units with limited lateral extent and varying reservoir quality, mostly tight due to quartz overgrowth cementation except when fractures are observed.

Furthermore, from petrophysical aspect the tight quartzite sandstone with the presence of fresh water, causes the resistivity to be high, beyond conventional tool limit. This leads to a difficulty to compute saturation profiling & distinguishing between oil & water.

Full evaluation techniques were utilized to characterize & identify potential zones to enable flow of black & heavy oil in such poor quality, complex reservoirs. The advancement in the interpretation of image logs, petrophysical logs lead to guide the reservoir Formation Testing Tools to enable flowing of black & heavy oil in such tight, complex reservoirs & conducting a Mini-Drill Stem Testing for reservoir potential assessment.

These wells when produced earlier had no signatures of heavy oil.

This paper describes the advancement in integrated approaches in Wireline logging to fully characterize such complex environments which resulted in the discovery of black & heavy oil in unprecedented area.
Integrated Automation and Intervention Solutions for Extended ESP Run Life in Complex Reservoir Environments
Authors: Hammad Mustafa , Musbah Ahmed. M. , Abdulatif W. , Shanbour H. , Masoud Mohamed H. , Elhajjaji R. R. , Awedan H. , Elhamali B. , Anabtawi E. , Budeeb M. , Bosnina S. , Bunkheila K.
Published: October 2024

A remote field that was discovered in 1970 relies on natural flow, supplemented by electric submersible pumps (ESPs) in some wells, to produce oil from a thin-limestone reservoir. With extensive faulting and low permeability, the primary recovery mechanism is solution gas drive. ESP systems previously struggled to achieve optimal run life, prompting the development of integrated solutions to extend the run life in challenging conditions.

Detailed failure analysis proved that the primary cause of ESP failures was motor overheating, exacerbated by inadequate reservoir influx. Therefore, a comprehensive integrated intervention workflow was developed to optimize ESP operation within this complex environment. First, a dual approach to stimulate the reservoir formation encompassed acid treatment and fracturing with rod-shaped proppant to mitigate the risk of proppant flowback and premature ESP failure. Addressing challenges such as deep reservoir pressure decline and a high gas-oil ratio, a wide range of a mixed-stage pump types and multiphase gas handlers were installed. Additionally, motor derating, tailored ESP shrouds, and variable speed drive technology were employed to optimize ESP operation. This included continuous 24/7 monitoring and remote control for enhanced performance.

The successful implementation of the workflow has delivered historical ESP run life exceeding 1 year in the field, coupled with sustained oil production. The first deployed ESP system yielded an average daily oil rate of 520 BOPD, prompting the extension of the approach to an additional four wells, resulting in a total rate of 3,750 BOPD. Continuous monitoring of well performance, facilitated by an automated workflow, has enabled the maintenance of optimal operating conditions. This includes fine-tuning the ESP running frequency to each well's performance, accounting for variations in well flowing pressure and reservoir fluid properties, such as different bubble points leading to varying gas-lock settings. Continuous monitoring and remote operation have minimized downtime to a remarkable 4.5%, which was mainly due to scheduled maintenance of the power system. This result verifies the effectiveness of the implemented solutions in optimizing field performance and maximizing hydrocarbon recovery.

The success of this approach has sparked interest in its application to similar reservoir environments, potentially unlocking additional oil potential in nearby fields. This promising prospect underscores the potential impact of our findings on the broader oil production landscape, paving the way for enhanced reservoir management and increased hydrocarbon recovery in comparable geological environments.
A Data-Driven Agile Approach for Faster Response to Lost Circulation
Authors: Sharma Sunil , Converset Julien , Le Blay Florian
Published: October 2024

In this paper we introduce a data-driven agile method specifically designed, implemented, and validated to yield actionable insights for more efficient and accurate responses to lost circulation events. Lost circulation is a significant challenge in drilling operations, leading to non-productive time and financial losses. It is also frequently observed that despite similar field conditions, the success rates of various solutions vary widely due to a lack of insights about the loss zone during planning and execution. Traditionally, response plans and decision trees are not dynamic and rely on categorizing loss rates as seepage, partial, or total losses. However, these plans often overlook critical factors such as the types of losses (e.g., natural fractures, induced fractures, vugs) and dynamic changes over time in loss rates, wellbore stresses, and pressures. Thus, developing a solution that processes these changes in near real-time to provide automated insights to the person monitoring the event can improve the success rates of our loss event response.

Additionally, there exists a disconnect between the multiple tools available for addressing lost circulation. These tools, when used together, can help in driving actionable insights and accurate detection of losses; i.e., active pit tracking by mud logging and mud logger's real-time comments, annular pressure while drilling (APWD) bottomhole pressure anomaly detection, geomechanics pressure wellbore limits, etc. Finding a way to bring all these tools and technologies to one platform so they can collaborate and complement each other can be a game changer in the precise detection of loss events and rates.

While developing the solution, numerous complexities were observed in pursuing a fully automatic method to put these multiple data sources together and drive a comprehensive outcome with the required precision, thus the concept of keeping a human in the loop was adopted.

In this paper, we delve into the details and uniqueness of the lost circulation monitoring workflows. We discuss the methodology used during workflow development and the establishment of a well-defined system for workflow validation using a labeled database. An overview of the uniqueness of the workflow computation, workflow verification process, and tiering of a workflow based on the quality of inputs and outputs will also be provided, along with the results of the real-time job applications and their successes.
Building a Sustainable Workforce: Cross-Posting and Secondment Strategies in Indonesia's Oil and Gas Operations
Authors: Endrawati Yohana , Putra Iswahyudi Sondi , Ningsih Retno
Published: October 2024

In today's disruptive era, marked by rapid technological advancements and evolving global conditions, human resources have become more critical than ever. Organizations must adapt quickly to remain competitive and sustainable. Effective human resource management is essential for attracting, developing, and retaining talent to navigate the complexities of the modern business landscape. Building a sustainable workforce—one that is resilient, adaptable, and continuously evolving—is crucial for long-term success.

Indonesia's oil and gas industry, a key contributor to the country's economy, faces unique challenges in this disruptive era. As a leading producer in Southeast Asia, the sector must continuously innovate and optimize operations to meet rapid technological changes, shifting market demands, and stringent environmental regulations. This demands a workforce that is not only highly skilled but also capable of adapting to new technologies and sustainability practices.

To address these challenges, the oil and gas industry must focus on preparing its human resources for the disruptive era while building a sustainable workforce. This includes equipping employees with the necessary technical skills and fostering continuous learning, adaptability, and sustainability. Aligning talent management strategies with the industry's evolving needs is essential for maintaining a competitive edge and supporting Indonesia's economic prosperity in a rapidly changing world.
Comprehensive Investigation for Gas Flaring Recovery as a Potential Pathway for Oil and Gas Decarbonization
Authors: ElMasry H.
Published: October 2024

The worldwide movement to cut greenhouse gas (GHG) emissions and drive decarbonization as a strategy to reach net-zero objectives is swiftly accelerating. It is broadly recognized as a key force influencing contemporary energy policies. While many nations have made significant environmental promises, the essential next phase involves converting these promises into concrete decarbonization initiatives with allocated financing.

Methane emissions within the oil and gas industry typically originate from three main sources: leaks (which occur unintentionally due to a defective seal or a leaking valve), venting (which happens when gas is deliberately released for safety or operational reasons), and flaring (which involves burning gas that cannot be utilized or recovered). The oil and gas sector faces significant pressure to lower greenhouse gas (GHG) emissions from non-emergency gas flaring and venting.

The urgency arises because these activities emit large quantities of methane into the atmosphere, which significantly exacerbates climate change and presents a major environmental challenge to reaching net-zero targets. Methane is regarded as the second-largest contributor to global warming after CO2. Despite having a shorter atmospheric lifespan than CO2, methane has a much stronger greenhouse effect. It is estimated to account for around 30% of the global temperature rise.
Exploring Hydrocarbon Reserves in Mature Oil Fields by Interpreting the Subsurface and Using Dynamic Modeling
Authors: Salim M. M. , Hamada G. , Dahab A. A.
Published: October 2024

An effectiveness study of building strategy nondrained oil reservoir blocks to increase hydrocarbon production from mature oil fields—dynamic modeling techniques with subsurface interpretations and sharply adjacent well data—offers new development well placements for oil recovery and field life extension.

The study combines production data, pressure surveys, and detailed subsurface studies— including well log interpretations—to develop proper understanding of the behavior of the reservoir for its performance estimation. Dynamic modeling techniques are applied in the estimation of optimal well placement. This multi-disciplinary approach is normally aimed at accurate reservoir characterization and making strategic decisions on the development of new wells in non-drained blocks. Its effective implementation may require studies by the geologist, engineer, and data scientist concerning comprehensive data analysis in formulating solutions.

Important results were that new development wells increased oil production by up to ∼15% in total field production. The approach has been of high value with limited risks/costs; characterized by a short payout period and good opportunities for reinvestment of the savings. It, therefore, identifies the potential for residual capacity unlocking from low-productivity or shut-in wells in the pursuit of maximizing an asset's value. This paper substantiates the effectiveness of strategic drilling through real field empirical evidence by featuring a convincingly logical workflow applicable to similar mature oil fields, hence lending practicality with respect to production enhancement and field life extension. Its effective implementation must be based on multi-discipline teamwork in order to complete an adequate analysis of the data available and formulate solutions.

This paper contributes new insights into the efficiency of production optimization strategy execution in mature oil fields. The combination of dynamic modeling with detailed subsurface interpretation enables the provision of valuable empirical evidence to a research study and mapping out the constructs of a systematic workflow that improves hydrocarbon recovery, extends the productive life of mature fields, and advances current knowledge in the petroleum industry.
Enhanced Well Delivery with the Application of at Bit Steerable System in Tough Reservoir Targets. A Case Study
Authors: Khurshid Muhammad Imran , Roomi Shamlan Al. , Varela Rodrigo , Almeer Ali , Ruzhnikov Alexey
Published: October 2024

The objective of this paper is to systematically device a detailed mechanism for engineering application of advanced at bit steerable system with motor and explicate development of directional plans, risk analysis along with mitigation and prevention plan for each possible option. The scope of this paper is to establish selection criteria and execution, performance objectives with applicable tools and post run analysis to help industry for future applications.

Drilling in a very challenging environment where the directional profile achievement always remained critical, it is important to deliver well within given timelines. Due to geological constraints and specific required reservoir contact, reservoir target objectives were set in really challenging steering options. Most of time such tough targets are not hit and resulting risk of well delivery delays and frequent risk of geological sidetracks. In an onshore field, during the planning phase given surface location and target reservoir coordinates were assessed, resulting real challenge in drilling long curved and horizontal sections.

In the given circumstance of reservoir Target entry and limited kick off point a systematic procedure was adopted to layout directional profile. A really difficult directional profile was built to geosteer from slanted pilot hole resulted into a highly challenging 3D directional profile. The directional profile needs to curve into the formations that always remain famous in posing risk to achieve required dog leg severity. The risk indexation was tabulated, and a process was devised to achieved required well profile. Moreover, challenges faced during the execution and key points, to make such application more successful, are also discussed in this paper.

The results of this case study lay out technical approach adopted to enhance performance as well as productivities that can be further optimized. This case study explains, detailed strategy and its implementation with the application of at-bit rotary steerable system (RSS) with motor to achieve required 3D target entry. This strategy explained how such tight targets can be achieved resulting into early well delivery with the application of at bi steerable system with motor. Application of at-bit steerable system along with motor resulted into smooth landing as per reservoir requirement and better steering into reservoir with enhanced contact area.

This paper cover methods that how this new technology at-bit steerable system with motor application supported in comparison to the other possible options to achieve highest performance with better control on directional profile