bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Systematic Approach in Developing Young UAE National Engineers as Part of Strategic Nationalization and Organizational Development
Authors: Al Karbi H. , Jamal Bahumaish M. , Unnikrishnan N. K. , Al Suwaidi M. , Alnuaimi M. , Alshamsi M. 
Published: October 2023

Abstract
Developing young engineers in oil field industry is crucial for the future of UAE, it is important to provide young engineers with proper training, mentorship, and opportunities to gain hands-on experience through systematic approach to build their technical skills and confidence. By investing in the development of young engineers, we can ensure that the organization remains resilient, innovative, efficient, and sustainable for years to come.
The general process of developing young employees is as follow: The community outreach to UAE Nationals, graduating from high school to study majors relevant to Engineering & Operations.HR on boarding team providing new joiners an orientation program about the company policies.Core discipline division.Overview about YDP "Young Development Program" training.Coaches and Mentors assigned to each young engineer.
In terms of methods and procedures that have been followed to assure the success of development process strategy, prior completing the training programs, the coaching mainly focus on practice & developing a learning curve, providing job opportunities, and required training enhancing technical experience & cooperating with shareholder and service companies to provide exposure of hands-on work. Not only that, but site experience is also essential for a wide exposure and knowledge on several operation jobs. Therefore, a weekly site visit is one of the essential methods that have been implemented and followed in industrial organization to develop the employees.
As a result, young national engineers are leading the technologies in Drilling, Engineering & Operations, Rigless Operations, Completion, Drilling Fluid and Drilling Planning. UAE young Drilling Engineers are also handling Unconventional Drilling Operations. Moreover, giving the opportunities to shatter stereotypes and pave the way for future female generations, young females has been assigned to site-based jobs. Furthermore, there is a noticeable increase in the number of national engineers, who are assigned to be Drilling Engineers, Drilling Fluid Engineers, Completion Engineers, and Project Leads.
With the progression of time, more UAE nationals have accepted the challenge and displayed enormous efforts and talents to break glass ceilings continuously within the Drilling Industry. Through the outreach programs, companies are displaying trust and faith in the young UAE national's prospect's abilities.
De-Carbonization: Zero Flaring by Acid Gasrerouting Project
Authors: Harish Somayajula , Satheeshkumar Ramalingam , Ashish Soni , Hamad AlMerri 
Published: October 2023

Abstract
Acid gases are produced as part of normal operation of Ethane crackers. Raw ethane contains impurities in minor amount consisting of CO2, H2S, COS and CO which need to be removed and disposed safely. These acid gases are removed in feed pretreatment section of the cracker unit and subsequently burnt in acid gas flare for safe disposal. Due to low calorific value of these components, some amount of natural gas is mixed with the acid gas to enable complete combustion and H2S destruction. Due to this addition of natural gas to the acid gases, there is always some amount of potential product being lost to flare. These additional emissions are due to natural gas injection which can be avoided by alternate routing of acid gas safely.
Enhancement of Drilling Effectiveness Through Lean 6 Sigma Methodology
Authors: ALAlawi A. S. , Peter J. , ALKindi A. , ALAdawi H. , Husaini N. , ALAlawi M. , AL Nuumani M. 
Published: October 2023

Abstract

Objectives/Scope
This paper highlights how PDO's Well Engineering Directorate adopted the Lean 6 Sigma methodology (using inferential statistics for problem solving) to improve the effectiveness of drilling 9.5/8" Multi-Stage Inflatable Packer Collar (MSIPC) tool. Furthermore, we explain how this data-driven technique helped us understand factors that influence drilling with this tool.

Methods, Procedures, Process
The Lean 6 Sigma methodology was implemented on multiple projects in Well Engineering. The term "Sigma" is used in statistics as an indicator of the degree of process variation. 6 Sigma is a structured approach that consists of five phases; Define, Measure, Analyze, Improve, Control (DMAIC).
Drilling the MSIPC tool is a repetitive operation but there is significant variance in its execution as drilling can vary from 30 to 240 minutes. There have been many failed attempts to optimise this process because they depended on people's experience only which boiled down to a trial-and-error approach.
In the "Define" Phase we outlined the business case and formed a team, sponsored by senior management. We then collected data from all jobs executed between 2019 and 2020 and visualised the data in different chart types to better understand process variation.
In the "Measure" Phase we conducted a workshop with all stakeholders, mapping the process end-to-end, identifying the main factors affecting the process. A Process Capability Diagram was used using Minitab (a statistics software), to assess the process baseline performance. We found that more than 70% of the jobs exceeded the upper specification limit of 60 minutes. We developed a Control Chart, which proved the process to be instable.

Results, Observations, Conclusions
In the "Analyze" Phase we conducted a graphical analysis (e.g., Matrix Plot, Main Effect Plot, Box Plot, etc.) and hypothesis testing (correlation and regression analysis) to determine which of the input parameters had a significant impact on the process time. The main findings were:
There was no significant relationship between the MSIPC drilling time and depth. There was a significant relationship between the MSIPC drilling time and Bit Type, Weight on Bit (WoB), Rotation per Minute (RPM), and Flow Rate.
Multiple regression analysis was then used to determine the relationship between significant input parameters and their combined impact on the result. From this, we were able to optimise the process parameters as follows:
WoB should be more than 4 kdaN, surface RPM should be 30-35, and Flow rate should be 1.5 m3/min. We were also able to conclude that PDC bits perform better for than Tricon bits.
In the "Improve" Phase we implemented the parameters the determined from the analysis on 10 wells and saw a significant process improvement. The average time to drill MSIPC reduced from 120 minutes to 55 minutes.
Enhancing Oilfield Management: The Digital Wellsite Advantages
Authors: Wang Xueqiang , Zhu Jun , Zhang Wei , Zeng Qijun , Zhang Zhicheng , Tan Yulong 
Published: October 2023

Abstract
Digitalizing has become increasingly important in the oil and gas industry as a way to reduce costs and increase efficiency. This paper focuses on discussing the application and benefits of digital wellsite, which provides the operator a novel way to integrate the real time information from various surface equipment and display in a digital twin panel. In this way, the company man could obtain the message about the performance of the asset instead of reading numerous sheets or daily report and do some further analysis. By utilizing 3D rendering engine and leveraging specific engineering algorithm the data could be transferred in a visualized and data-fused way, where the wellsite supervisor and office engineer could track onsite progress and take corrective measures if needed. This digital wellsite module provides insights into operational and environmental conditions that can improve safety and reduce risks associated with surface status. For example: the digital wellsite monitors the equipment data to see if it meets the requirement of the operation, and office engineer could check the onsite information only by click the mouse then the real time information of selected asset would be displayed in front of the user.
This digital wellsite collects onsite data and generates a digital twin wellsite, all data generated by onsite sensor would be appeared in this digital twin model, the operator could view the information they need just like playing a game or watching a movie. It could also help office man get a realistic understanding of field condition, making alert message to operator if onsite data would violate related rules and regulations so they can make some action in advance rather than remedy its consequences, for example the expiration of validity on BOP (blowout preventor) message could be monitored and avoided as digital wellsite would remind the operator a few days before it happens. All wellsite equipment's data would create a data lake and operator could manage their remote assets based on these valuable data, the digital wellsite could match the spare parts and coordinate in the most efficient way rather than deliver them from warehouse hundred miles away. On the way of energy transformation, the digital wellsite offers the oil &gas industry substantial potential benefits in terms of efficiency, cost savings, risk reduction and less carbon emission. Our industry needs us manage more operations and assets in less human resources and lower budget, the digital wellsite helps operators reducing their travels to field for inspection or goods delivery, and improving their efficiency on making decision since they could get the latest and fullest information in seconds instead of spending hours reading daily report or checking equipment sheets.
Figure 1 Traditional way of wellsite inspection via manual recording Figure 2 Digital wellsite adopts mixed reality device to execute onsite inspection.
AI-Assisted History Matching Application to a Large Onshore Carbonate Reservoir
Authors: El Droubi N. , Tahir S. , Maarouf A. , Su S. J. , El Jundi O. , Kloucha C. Kada , Mustapha H. 
Published: October 2023

Abstract
History matching a large reservoir model with high well count and long production history might be a challenging and time-consuming task, especially if it's done using only global multipliers as advised by common practice. Using local modification is unavoidable. This paper describes the application of an automated workflow creating local modifications on well-by-well regions. This application is done on top of the global multipliers and all the other uncertainty parameters. It's done to generate an ensemble of simulation runs leveraging machine learning proxy models to history match a large onshore carbonate reservoir.
We applied a machine learning (ML)-based optimization process to perform history matching with a large number of uncertainties. A ML proxy-model was built from an ensemble of reservoir simulation models capturing varying uncertainty parameters. The ML proxy-model captured field and well level simulation results assessing the quality of the history match. An optimization framework was defined in which to embed the ML model, minimizing the mismatch between simulation results and historical production/injection. The objective function as defined assesses history match quality by comparing the historical production/injection data with simulation results predicted by the ML model.
The workflow was successfully applied to a large onshore carbonate reservoir with approximately more than 1000 wells and 20 uncertainty parameters. An ensemble of simulations was generated to capture the variation of the uncertainty parameters. This ensemble was used to train a high-fidelity reservoir proxy-model that predicts field level and well level simulation results. The optimization results provided a set of parameters by minimizing the mismatch between the results predicted by the ML model and the historical production/injection data. As a result, a high-quality history match was obtained on the key parameters considered. The results were then validated by running the reservoir simulation model with the optimum uncertainty parameters, which delivered results very close to the ML model prediction.
The optimization process with a ML model is orders of magnitude faster than attempting to perform the history matching using the reservoir simulation model. The ML-based optimization for the history matching framework developed demonstrated good results on a complex reservoir model with a high number of uncertainties and high well count, paving the way toward significant field development planning acceleration.
Innovative PDC Bit Design to Improve Drilling Performance in Highly Abrasive Sandstone Reservoirs
Authors: Hussain Sajid , Jose Bustamante Rodriguez Victor , Boufama Chaouki 
Published: October 2023

Abstract
Drilling heterogeneous and abrasive sandstone reservoirs horizontally with conventional PDC bits pose significant challenges due to early worn out cutters requiring multiple bit trips. This negatively impacts rate of penetration (ROP) resulting in excessive time to drill and complete horizontal sections. This paper describes how the use of rolling cutter PDC bit technology, can overcome this challenge by improving ROP to drill the entire section in optimal time.
A detailed analysis of historic drilling parameters and bit dull gradings in the field showed that abrasive wear and chipping on bit shoulders was the most common dull characteristic causing reduced ROP performance and requiring a BHA trip for the bit change-out. To address the challenge, finite element analysis (FEA) was performed to identify the locations of high cutter wear. Subsequently, a new bit design with fully rotating cutters strategically placed at high bit wear locations was developed. The new design ensures that the wear on diamond cutter faces is minimized, and prolongs bit life durability.
In order to test the efficiency of the bit, it was run on a motorized rotary steerable (MRSS) assembly to drill one of the horizontal sections with abrasive sandstone. The bit drilled the entire horizontal length of around 4000 ft in a single run. Previous bit designs drilled through similar reservoirs with multiple conventional PDC bits, or in the best-case scenario, with low ROP in a single bit run. The new bit design achieved unprecedented results by delivering ROP performance with an increase of 100% compared to the average bit run. This improved performance eliminated the risk of extended open hole exposure which often leads to wellbore instability induced by reactive shales, further warranting a dedicated reaming trip. Historic analysis also determined that conventional PDC bits fitted with premium cutters uses only a small portion of the diamond table to contact the formation. Once the diamond table on the cutters face gets worn or chipped, the drilling efficiency is compromised. These worn flat cutters generate a high degree of frictional heat while drilling through the abrasive sandstone, which breaks down the diamond bond. The new bit design with fully rotating cutter technology does not face the same challenge.
The paper will also discuss how precise positioning of the diamond cutting elements relative to contact with the formation is a prime concept to achieve efficient element rotation in order to keep the elements sharp for long intervals. As a result, roller diamond element bit durability is sustained and drilling run length is increased in comparison to conventional fixed cutter bits.
Innovative Method to Understand Flow Behavior in Horizontal Wells with Challenging Borehole Conditions Using Spectral Noise, High Precision Temperature and Pulsed Neutron Logs
Authors: Naser Ethar Al , Noureddine Benlakhdar 
Published: October 2023

Abstract
Understanding flow behavior in horizontal and highly deviated oil producers is crucial to optimize production strategies and ultimately improve hydrocarbon recovery. Traditionally, multi-phase production logging provides flow profiles and fluids entry points in horizontal wells. However, this technology may be less effective for boreholes with challenging conditions such as the presence of sticky material that cause the loss of measurement tool sensors. This paper proposes several techniques, including spectral noise logging, numerical temperature simulations, and pulsed neutron logging as alternatives to provide flow profiles, identify formation fractures, and characterize possible cross flows in horizontal oil producers with high water cut in the presence of sticky deposits.
The tool strings of spectral noise, high precision temperature and pulsed neutron logs contain no mechanical parts or exposed probes that could get affected by sticky deposits. The spectral noise log allows identifying flow zones and fracture signatures. An advanced numerical temperature simulator can be used to quantify total flow that correlates with changes in temperature gradients, while pulsed neutron logs provide water flow using carbon-oxygen for three-phase holdup thereby allowing oil flow to be estimated by subtraction the water flow rate from the total flow.
The presence of sticky deposits can compromise the ability of mechanical spinners and exposed probes to provide accurate flow profiles without the use of expensive chemical treatment. The proposed approach will provide a complete high-resolution flow profile comparable to mechanical spinners, while also looking deep into the reservoir and correlating the profile with borehole fractures. Also, the flow profile can be generated using the total acoustic noise power of the turbulent flow. The results of both numerical simulations and acoustic flow velocity compared well with the flow profile provided by the mechanical array production tools.
The combination of spectral noise, high precision temperature and pulsed neutron logging suite provides valuable reservoir information without the use of any mechanical parts or exposed probes that could be affected by sticky deposits.
Development and Evaluation of a Novel Non-Combustion Gas Turbine for Offshore Platform Application
Authors: Muhammad M. F. , Thant M. M. M. , Firmansyah Firmansyah , Daud N. M. R. N. M. , Sedaralit M. F. 
Published: October 2023

Abstract
In this paper, a series of steps for validating a Computational Fluid Dynamic (CFD) model of a novel impulse gas turbine generator is investigated. An impulse gas turbine generator is a small scale and compact electric generator designed to provide power to remote offshore platforms. The generator is driven by pressurized gas and generate power through expansion of the gas. As the effluent gas is designed to be redirected to lower pressure gas line, the generator provides clean energy with higher reliability and no dependency on weather if compared to solar panel technology that is widely used. As a new technology currently being developed and tested, the operating data of the generator is very limited, and the performance expected when deployed later cannot be ascertained. To ensure that the impulse gas turbine generator performs as per intended, numerical approach by using CFD is adopted where CFD model by using sliding mesh method have been developed. The simulations result is then validated with experiment results where the very small deviation is observed between the two results. With validated model, performance under natural gas or methane-rich condition is simulated and tested. Despite the different in gas composition, performance expected from CFD model is very similar to the actual result observed during the gas flow loop test.
Multizone Open Hole Gravel Pack Completion with Selective Production Capability in ACG Field
Authors: Susilo Yoliandri , Dharmadhikari Khsitij , Taha Sherif , Ismayilova Ayisha , Guliyev Ilkin , Jafarli Zaur , Kerimov Natig , Kerimova Ravana , Veliyev Samir , Whaley Kevin , Wallace Alex , Mammadov Elvin , Foster Mike 
Published: October 2023

Abstract
Azeri-Chirag-Gunashli (ACG) is a giant field located in the Azerbaijan sector of the Caspian Sea. The major reservoir zones are multi layers sandstone formations and weakly consolidated where Open Hole Gravel Pack (OHGP) completions have become the standard design for production wells. To date more than 170 high rate OHGPs have been completed that are producing comingled from multi-layered sandstone formation.
As the field matures, problems such as premature water and gas breakthrough are becoming increasingly common requiring the completion system to be inherently flexible to address such issues. The Multi Zone OHGP concept design has been developed to manage this increasing reservoir management complexity. Zonal isolation and selective production capability are achieved by installing combination of multiple Screen PBR and/or open hole packer in combination with seals unit and mechanical sliding sleeve in the inner string at the intermediate completion, and Inflow Control Valve (ICV) at the upper completion.
To date, two Multizone OHGP wells have been completed successfully. The Screen PBR system has proved to provide effective zonal isolation or baffling. This system allows flexibility to deal with unexpected reservoir surprise (wet/gas zone) that requires zonal isolation on day-1 without major changes in completion design, thus reducing rig time & operational cost.
This paper discusses design, execution, and result of the first two Multizone OHGP completions installed in the ACG Field. Installing multiple Screen PBR to provide baffling against crossflow is a novel concept. This technique does not compromise gravel pack quality or sand control integrity. The success seen with this technique makes a compelling case to further develop the concept on a larger scale in ACG and maximize field recovery.
Miscible Water Alternating Gas Injection WAG Field Scale Application in Algeria: An Effective Way to Improve Oil Recovery, Rejuvenate Mature Field and Develop Opportunities to Stream Gas Sales
Authors: Allal M. A. , Brancolini A. , Smail F. , Kaaroud Z. , Kriat M. A. , Elmutardi M. 
Published: October 2023

AbstractWater alternating gas (WAG) injection technology is methods which may improve oil recovery efficiency by combining the effects from two traditional techniques—water and gas flooding. Both microscopic oil displacement and sweep efficiency can be enhanced by WAG implementation (Surguchev et al. 1992). WAG injection consists of injecting water and gas from the same injection wells which contribute to the improvement of overall sweep efficiency by: