bluuebunny/crossref_metadata_2025_split huggingface dataset:
Sistem Pakar Mendiagnosa Penyakit Mata KatarakDengan Metode Certainty Factor Berbasis Web
Authors: Fahmi Hasanul 
Published: October 2019

<p><strong>Katarak merupakan penyebab utama gangguan penglihatan dan kebutaan di Indonesia. Saat ini kebutaan di Indonesia yang disebabkan mata katarak mencapai 30% pada umumnya berusia 50 tahun, sehingga hal ini menjadi hal yang layak untuk di teliti. Dengan kemajuan teknologi yang semakin canggih dan kurangnya tenaga ahli dibidang mata sehingga dibutuhkan sebuah sistem pakar yang mampu menyamai dengan ahli pakar dengan harapan dapat membantu masyarakat agar lebih awal mengetahui tentang penyakit mata katarak sebelum menderita penyakit mata katarak. Adapun metode yang digunakan untuk mendiagnosa penyakit katarak yaitu dengan menggunakan metode <em>Certainty Factor </em>dimana metode CF menunjukan nilai kepastian dari suatu fakta yang belum pasti dan memperoleh tingkat persentase dengan</strong> <strong>nilai 95% sehingga dengan adanya metode <em>Certainty Factor</em> dapat digunakan untuk mengetahui masing- masing pada setiap gejala.</strong></p>
Şiddet İçerikli Bilgisayar Oyunlarının Ergenlerin Saldırganlık Eğilimine Etkisi
Authors: EVCİN Savaş , ERZİ Seda 
Published: October 2019

Bu çalışmanın amacı, şiddet içerikli video oyunlarının ergenlerin saldırganlık eğilimlerine etkilerini incelemektir. Çalışma Tunceli ilindeki yatılı bölge okullarında yapılmıştır.. Katılımcılar, yaşları 11 ile 16 arasında değişen 75 erkek ve 75 kız ergenden oluşmaktadır. Katılımcıların %94.6'sı aile evlerinde bilgisayar ya da video yunu konsoluna erişememektedir ve bu türden oyunu ilk defa oynamıştır. İlk olarak katılımcılara demografik bilgi formu ve Buss-Perry Saldırganlık Ölçeği uygulanmıştır. Daha sonra katılımcılar rastgele 4 deney grubuna atanmışlardır ve 2 saat veya 15 dakika boyunca şiddet içerikli (GTA) ve şiddet içermeyen beceri oyunu (Tumblebugs) oyunu oynamışlardır. Beş gün sonra saldırganlık ölçeği tekrar uygulanmıştır. Şiddet içerikli oyun türünün, oynama süresinin ve bu değişkenlerin etkileşimi etkisinin, ön test puanları kontrol edildikten sonrasaldırganlık eğilimini arttırdığı bulunmuştur. Daha uzun süre (2 saat) şiddet içerikli oyun oynayan öğrencilerin saldırganlık puanları, daha az (15 dakika) oynayanlardan anlamlı düzeyde yüksek bulunmuştur. Çalışmanın sonuçları literatür ışığında tartışılmıştır. Araştırmanın sonuçları, şiddet içerikli bilgisayar oyunu oynamanın saldırganlık eğilimini artıracağını savunan görüşleri doğrular niteliktedir.
Hands-On Knowledge Transfer from Shell to KOC through Structured Framework Called Technical Competence Ladder TCL
Authors: Dashti Qasem , Moosa M.H.. H. , Erdman M.. , Jensen P.. , Olusegun Kolawole , Al-Qadeeri Bashar , Dhote Prashant 
Published: October 2019

Abstract
Kuwait Oil Company (KOC) is going through many new challenging projects that aim to increase its hydrocarbons production capacity by 70%. The North Kuwait Jurassic Gas Fields project is one of the key projects with unique challenges from the subsurface complex and challenging characteristics of deep reservoirs, high pressure high temperature (HPHT), high in H2S and CO2 concentration-to the design, construction and operating of surface facilities. The Gas Field Development (GFD) group was established in 2007 to manage and accomplish KOC’s desired objectives from the NKJ Gas Fields project. The new group had to recruit manpower and build the required technical skills to address the unique challenges. End of 2010, KOC-GFD entered into an Enhanced Technical Service Agreement (ETSA) with Shell in order to benefit from the International Oil Company (IOC) expertise. One of ETSA objectives is to develop local KOC staff through Knowledge Transfer, whereas challenge was more than 60% of the total GFD population were juniors, i.e. less than 4 years of experience.
The need to fast track the development of the new recruited staff was identified by the management as a critical key element to overcome the project complex challenges. The development of a new approach for staff development using the best of both worlds’ i.e. building on KOC’s training programs and supplementing with Shell Jurassic ETSA Knowledge Transfer resulted in the creation of the Technical Competence Ladder, TCL, framework for all GFD staff in 2017. This technical paper will describe how the Jurassic ETSA Knowledge Transfer–progressed over the course of the contract;–connected with GFD business objectives;–used key methodologies for successful application in the day-to-day activities;–promoted a performance-based learning environment;–used critical resources with clear accountabilities;–was monitored and measured continually;–Implemented with structured approached.
The results include the development of Structure and detailed competence skills development program for main subsurface disciplines like: Reservoir Engineering, Petrophysics, Geosciences, & Petroleum Engineering. Each main discipline includes number of specialization and focused sub-programs. The TCL program was implemented, and the Knowledge Transfer are proven. The progress of junior staff competences has been tracked and measured over the years; the creation of motivated and competent workforce has resulted in improved performance and increased team productivity. The overall results reduced ‘existing’ competency gaps within the company, enhanced communication between junior and senior staff, improved staff confidence and work performance. Key examples of success will illustrate the points covered in the technical paper.
Wells Intervention Cost Optimization Through Curing Formation Damage in Sabriya Wells- Case Study from Kuwait
Authors: AL-Rashidi Hamad , Jamal Mariam , Duncan Bruce , Al-Mousawi Abdullah , Al-Sagheer Asma , Al-Mosaileekh Safia , Al-Husaini Mohammad , Ali Mohamed 
Published: October 2019

Abstract
North Kuwait Sabriyah wells have massive formation damage and enormous fluid losses occurring during workover operations in the Upper Burgan Formation. This challenge causes wellbore plugging, as well as incremental operational costs (rig days & brine cost) and delayed production. It is noteworthy that the Upper Burgan (UB) Formation is balanced with 5.5 PPG kill fluid. This is due to the significant differential pore pressure and 8.4 PPG brackish water, which would impose a high risk of losses and formation damage.
A unique solution" salt pill" has been selected as an optimum solution to this challenge. The solution is a filtration control agent that allows work over activity with temperature stability up to 350 Deg. F and it is applicable for Gas & Oil wells with over 2% water cut. It is sustained casing pressure for workover with a constant fluid level at surface during the intervention. The customized fluid is being flowed back and it is 100% dissolvable in produced or any under saturated water, with no need for acid breaker. This unique feature allows to keep the formation up to 5000 Psi overbalance thus eliminating potential well control issues by maintaining the static fluid level in the well.
This salt pill technology was successfully tested in the candidate Sabriyah wells, the results were satisfactory & the trail has shown good success. The well was put back to the original rate, and oil showed at surface after unloading only one well volume.
This successful pilot will be a best practice solution for KOC assets in term of cost optimization and added value. The technology will support KOC to solve some of the other faced challenges in various wells integrity and WO issues demonstrating how much cost savings can be attained along with keeping the reservoir damage free and restoring its productivity to original levels after the Salt Pill technology has been deployed.
A Practical and Economically Feasible Surfactant EOR Strategy: Impact of Injection Water Ions on Surfactant Utilization
Authors: Al-Murayri Mohammed Taha , Al-Qattan Abrar , Kamal Dawood S. , Winoto Winoto , Li Zhitao , Britton Chris , Delshad Mojdeh 
Published: October 2019

AbstractA comprehensive chemical enhanced oil recovery (CEOR) laboratory evaluation program was carried out to compare surfactants for alkali-surfactant-polymer (ASP) and surfactant-polymer (SP) implementation in a giant Middle East sandstone oil reservoir. The efficacies of ASP and SP floods were investigated in laboratory corefloods and simulations with emphasis on surfactant retention to improve techno-economic feasibility.ASP and SP flooding processes were designed with low operational cost in mind and tested in laboratory corefloods. Different injection water salinities were considered for practical field application. The handling and availability of injection water with a suitable composition has significant implications in CEOR projects. SP design using produced brine with minimum water treatment is an attractive option for commercial deployment. We considered different injection water salinities, surfactant molecules, and brine treatment requirements for several ASP and SP designs.ASP and SP corefloods recovered nearly all of the remaining oil after waterflooding. The surfactant retention was lower for SP floods when brine with reduced concentration of Ca2+ and Mg2+ (hardness) was used. Both ASP and SP formulations were also tested for crude oil samples from different zones. A minimal adjustment in injection salinity was required for different oils with our surfactant formulations. Surfactants designed for easy manufacturing and supply availability performed well with brine compositions that require minimal treatment. Field implementation strategies were evaluated via numerical simulation. The effect of strong aquifer drive on SP performance was shown to be minimized with optimized injection/production strategies. SP was shown to be technically and economically an attractive candidate tertiary process.
Mitigation of Calcium Sulfate Scale Deposition During Fracturing Treatments
Authors: AlOtaibi Fares , Dahlan Mohammed , AlGhamdi Abdulaziz , Sadykov Almaz , Mechkak Karim 
Published: October 2019

AbstractCalcium sulfate scale precipitation is a challenge especially during stimulation treatments. The main objective of this study is to mitigate calcium sulfate precipitation during fracturing treatment. With high sulfate content in source/mixing water up to 2,000 parts per million (ppm) and excessive of total dissolved solids (TDS) formation water that can reach 60,000 ppm calcium.An experimental study was conducted at the reservoir downhole temperature of 280°F to evaluate the formation water compatibility with source water wells used for fracturing fluids. The sulfate content varied in the fracturing fluids up to 2,000 ppm. This paper addresses: the scaling tendency of water-water interaction; the efficiency and minimum inhobitor concentration of three commercial calcium sulfate scale inhibitors; the stability of high sulfate fracturing fluids at 280°F (138°C) with scale inhibitors.This study indicated: water-water compatibility tests reinforce the mineral risk assessments findings for calcium sulfate scales, scale inhibitors were effective to prevent scale deposition when added at 1.5 gpt to the source water. The high pH-fracturing gelled fluids must be prepared using relatively low sulfate water (SO42- ≤ 500 ppm). The scale inhibitors, when added to the high pH-fracturing, gelled fluids at minimum inhibit concertation will not negatively affect the polymer gel rheology and adhesion.The study set guidelines to prevent calcium sulfate scales issues during fracturing jobs with incompatible source and extreme salinities formation water. The lesson learned exhibits an effective practice to maximize treatment efficiency and minimize formation damage that could be induced during fracturing.
SARA-Based Lumping Scheme: An Application Example
Authors: Altowilib Ali R. , Fraim Michael 
Published: October 2019

Abstract
Reservoir fluid properties play a crucial role in the upstream field development cycle. Petroleum engineers extensively utilize Pressure-Volume-Temperature (PVT) studies in applications such as calculations of pipelines’ pressure drop, and assessment of Enhanced Oil Recovery (EOR) strategies. These studies are generated from a series of lab experiments conducted on reservoir fluid samples in high pressure-high temperature (HPHT) lab environments, and commonly matched using Equation of State (EOS) software.
Feeding and characterizing the composition of a reservoir fluid in a PVT software play a central role towards understanding its behavior. These steps are heavily affected by the last carbon number measured and the lumping scheme used in the simulator. This paper investigates the application of splitting the plus fraction, and utilizing Saturates, Asphaltenes, Resins and Aromatics (SARA) analysis in enhancing viscosity prediction at atmospheric conditions.
In this study, three oil samples from fields with suspected flow assurance issues were selected. A fingerprint study was first conducted on all samples to ensure that they are representative of the original reservoir fluid, and free of any drilling fluid contaminants. The methodology used in this study is based on conducting compositional analysis and viscosity test on the selected samples. Furthermore, SARA analysis was conducted to enhance the characterization of reservoir fluid, and confirm asphaltene presence. Lastly, splitting technique and SARA-based lumping scheme were used to predict viscosity values at atmospheric pressure and were compared to experimental data.
The results of this work demonstrated the effectiveness of SARA-based lumping scheme on atmospheric viscosity prediction, which captured the plus fraction concentrated in the dead oil without compromising the computational time. Furthermore, the EOS software used studied the sensitivity of the simulation results to different compositions.
Development of an Integrated Wells - Pipeline Networks - Process Facilities Model for the Greater Burgan Oilfield from a Model Centric Approach
Authors: Desai Sameer Faisal , Al Jadi Issa , Al-Ghanim Wafaa , Al Sabea Salem H. , Al-Haddad Saud M. , Franco Francy Milena , Khor Siew Hiang , Bodwadkar Suhas V. , Saxena Aditya , Zhang Qiong Michael , Hapsari Hairuni Safri , Morales Fernando , Halabe Vijaya 
Published: October 2019

Abstract
Several efforts have been made in the past for generating an Integrated Asset Model (IAM) for the Greater Burgan field in Kuwait with mixed results on sustained utilization and benefits. A new effective full field Integrated Asset Model has now been developed within an Integrated Operational Excellence (IOX) program towards Digital Transformation of the Greater Burgan field.
A proven model centric approach has been adopted to bring multiple interdependent wells, pipelines networks, and process facilities models together into one single truly integrated asset model. The IAM platform also includes a water processing facility model which consists of 2 effluent water disposal plants, a crude oil export pipeline network and a water injection network model. Development of this integrated wells-network-facility-crude export-water processing facility-water injection network model incorporating the 14 gathering centers in the South and East Kuwait (SEK) asset focused on providing all the essential valuable inputs to business processes for better asset management, faster and more accurate decision-making and optimizing the hydrocarbon flow path all the way from the reservoir till the export point. The assessment was done at full field level where the complete system constraints, interactions and back pressure effects between more than 2000 different wells were fully accounted up to the crude processing facilities.
The availability of this fully integrated asset model with up-todate calibrated wells and network models and process models enables Kuwait Oil Company (KOC) engineers to better understand current well performance and production potential, identify any possible bottlenecks imposed by the large complex surface network and process facilities of Greater Burgan Oilfield. The simulated results such as pressure gradient, temperature gradient and erosional velocity ratio gradient across the production networks are presented on the GIS map for easy opportunity identification.
The paper describes how the Integrated Asset Modeler tool enables the asset teams to evaluate different operating scenarios to further enhance well performance and the overall asset productivity via re-routing well flow path to an appropriate header, identifying well workover opportunities, re-evaluating artificial lift design, adding new wells for field development and comprehensive understanding of well integrity and flow assurance studies. The integrated asset model can be coupled to the Greater Burgan reservoir model for comprehensive field development studies in future.
Disruptive Change to Correct Our Myopia in Enterprise Risk Management
Authors: Ali Al-Haidar , David Gurney , Craig Williams 
Published: October 2019

Abstract
Welcome to the future of ERM transforming from descriptive to analytic data for the risk register as the main objective because the risk register without statistical analysis equates to myopia, like a Heliographic Alphabet without the Rosetta Stone to translate. The scope of this paper is to demonstrate a statistical approach for the risk register where until now decisions have been made on descriptive data.
A proactive analysis is used in this paper to analyze the risk register data that will enhance our understanding of the risk register’s items to subsequently make better decision. The approach is to quantify the descriptive data in a statistical platform called SPSS (Statistical Package for Social Sciences). The quantified data is first tested using Coefficient Alpha analysis. Coefficient Alpha measures the reliability of the coded data, that is the accuracy level of the likelihood and impact items in the risk register. Coefficient Alpha is a matric that attempts to reflect our mindset or cognitive level during the risk assessment phase. Reliability is expressed as a number ranging between 0 and 1, where 0 indicating no reliability (much error) and 1 indicating perfect reliability (no error) (Peter 1979).
The result of Coefficient Alpha analysis is a composite score (%) to aid whether to progress to the next stage. The entire coded data is uploaded to the SPSS platform or Microsoft Excel to analyze the data for correlation and regression of the assessment items that affect the risk degree in the risk register. From observations related to the scale of likelihood with impacts levels, and the chosen items should be revised because their correlations will be in degradation mode after time. The new method is wider than the current approach, leading to better decisions about how to treat high and very high risks. In the new method the risks to be treated will be selected based on which items from the evaluation list are most affecting the risk degree.
The new method can form a comprehensive of risk management. This will enhance our understanding of the risk register in the petroleum industry, enhancing reporting, as well as removing some evaluation items that have no effect on the risk degree and adding alternative items in the risk register.
Challenges In Operating A Digital Oilfield - Lessons Learned From The Burgan Integrated Digital Field Pilot
Authors: Desai Sameer Faisal , Rane Nitin M. , Al-Shammari Baraa S. , Al-Sabea Salem H. , Al-Naqi Meqdad 
Published: October 2019

Abstract
Kuwait Oil Company initiatives for ushering in a new era of digital transformation of its assets to intelligently and optimally manage the Oil and Gas fields were successfully realized with the completion of three pilot projects entitled Kuwait Integrated Digital Fields (KwIDF). This paper discusses major achievements of the Digital Oilfield technology implemented in Burgan KwIDF project and provides an insight on the challenges in operating it.
The Burgan KwIDF pilot successfully transformed GC-1 production asset into a fully instrumented DOF comprising of digital instruments and infrastructure installed at well site and the production facility. Real-time production data is transmitted to a state of the art collaboration center that integrates data continuously with automated workflows for validation, modeling and tuning of well and facility models. Right time decision support information generated from smart visualization tools allow quick actions for production optimization, well and facility management in a collaborative work environment.
There is persistent value realization from KwIDF technology implemented in Burgan field. It has generated substantial cost savings with faster response time in restoring production and reduction in non-productive time. Driven by the digital environment asset production has sustained at target as production gain opportunities are capitalized and losses compensated quickly.
Over the period of time with experience in utilizing the DOF technology it has been observed that the technology sustainment is dependent on the technology providers to a large extent. The main components that require their continuous support are the digital instruments, proprietary software, hardware and related infrastructure. Technical expertise in each domain is necessary for ensuring continuous and smooth operations in the field, wellsite and collaboration centers. Development of an integrated team of domain experts is crucial for successfully managing the DOF operations. Change management initiatives for developing an in house user champion team is mandatory for ensuring sustainment. The important lessons learned and solutions are discussed in detail.