bluuebunny/crossref_metadata_2025_split huggingface dataset:
La Innovación para la Generación de Valor en los Procesos de Calidad
Authors: Fontalvo Herrera Tomás 
Published: November 2017

En este artículo de refl exión se presentan los conceptos y criterios necesarios para desarrollar procesos de generación de valor soportado en procesos de innovación y calidad con un enfoque sistémico convergente, con lo que se gestiona el conocimiento para crear satisfacción a los clientes con metodologías prácticas en los contextos donde se aplique. Como resultado de este artículode reflexión se aporta al sector empresarial una metodología con la cual se pueden desarrollar procesos de cambio y mejora en el contexto donde se interviene.
Systemic manifestations of atrial myxoma
Authors: Mir Ishtyak Ahmed , Ali Noor , Kohli Arvind 
Published: November 2017

Background: Approximately 70% of the cardiac tumors are benign, atrial myxoma is the most common, and is seen more in females. Presentation is variable, and patients can present with cardiac symptoms or systemic manifestations. Prognosis may be grave if the presentation is late or if the diagnosis and surgery is delayed. Accurate diagnosis, early surgical intervention gives excellent results.Methods: The study was conducted in the department of cardiovascular and thoracic surgery, all the patients who had diagnosis of cardiac myxoma irrespective of age, sex and associated diseases were included in the study. Transthoracic echocardiography was the initial investigation of choice, in some vascular Doppler studies, and CT scan was also done. All were operated under cardiopulmonary bypass, myxoma was approached by left atriotomy, tumor along with its base was excised, and the defect so created was closed directly or a patch repair was done.Results: Majority were in 5th decade of life, females were more. Presentation included breathlessness, edema, hemiparesis, monoparesis, aphasia. Clinical examination revealed anemia, dyspnea, edema, audible murmur, weakness of limb/limbs and aphasia. Echocardiography established diagnosis in all. Left atrium was the common chamber involved. Interatrial septum on left atrial side was the common site of myxoma origin. All had uneventful post-operative period, and there was no mortality.Conclusions: Atrial myxoma, though very rare, can present with a grim phenomenon, early and accurate diagnosis, followed by excision under cardiopulmonary bypass gives excellent results.
LITERASI ASESMEN IPA
Authors: Suciati Rizkia , Amirullah Gufron 
Published: November 2017

Penelitian bertujuan mengetahui literasi asesmen dari guru-guru sekolah dasar di Bengkulu. Survei dilakukan terhadap guru sekolah dasar (n = 28) yang berasal dari 22 sekolah dasar dari 5 kecamatan se-kota bengkulu. Responden diminta melengkapi 4 pertanyaan tertutup dan 5 pertanyaan terbuka berkenaan dengan tingkat literasi asesmen, tujuan utama dari asesmen dan pemanfaatan berbagai teknik asesmen, kebutuhan akan pelatihan lanjutan dan cara-cara yang disarankannya untuk meningkatkan literasi asesmen di perguruan tinggi dan pada praktek keguruan (PPL). Sebagian besar responden menilai tingkat kemampuan asesmen mereka relatif baik, meskipun hal itu bertolak belakang dengan pendapat mereka tentang tujuan asesmen. Tujuan sumatif masih mendominasi sebagai tujuan asesmen dalam pembelajaran, sedikit yang berpendapat asesmen dilakukan untuk keperluan formatif (pengembangan) dan diagnostik. Mereka lebih menyukai menggunakan teknik asesmen komunikasi personal dan tes pilihan (responden terbatas), namun bila ada pelatihan teknik asesmen di masa mendatang mereka memilih teknik asesmen observasi. Perguruan tinggi dapat berperan dalam pengembangan literasi asesmen calon guru dan guru, termasuk melalui kerja sama dengan Dinas Pendidikan.
Innovative Production Optimization Technique for Smart Well Completions Using Real-Time Nodal Analysis Applications
Authors: Al-Anazi Amer M. , Isichei Obi L. , Al-Yaha Mohammed A. , Al-Shammeri Faleh M. 
Published: November 2017

AbstractSmart/Intelligent well completions are broadly used to maximize multilateral well productivity, restrict unwanted water and gas production, and improve sweep efficiency. To achieve the optimum economic values of smart completions, the surface and subsurface chock valves settings need to be frequently optimized using the best-in-class techniques. Applying the right optimization technique will ensure a successful and efficient optimization.The paper discusses an innovative production optimization approach using real-time modeling based on nodal analysis for multilateral wells. These multilateral wells are equipped with surface and subsurface downhole valves with various choke settings and downhole permanent pressure gauges. The technique utilizes the data collected during a conventional optimization and a commercial steady-state model. It estimates the flowing parameters of individual laterals, determines the optimum pressure drop across each downhole valve, and estimates productivity of each lateral during the commingled production at various choke valves settings.The approach was successfully field-tested and validated. The generated models were used to predict well performance at various conditions. The approach starts by collecting well rates and flowing bottom-hole pressure data at various chokes settings including commingled and individual lateral testing. The acquired data are used to calibrate the model, generate different production scenarios and optimize the performance of each lateral.Adoption of the technique among others facilitate better management of the multilateral wells production to fulfil both short and long term objectives, namely, optimizing production of these wells and improving recovery. In addition to the reduction of OPEX associated with the conventional procedures to test and optimize these wells.
Wettability Alteration of Carbonate Rocks via Nanoparticle-Anionic Surfactant Flooding at Reservoirs Conditions
Authors: Al-Anssari Sarmad , Nwidee Lezorgia N. , Arif Muhammad , Wang Shaobin , Barifcani Ahmed , Lebedev Maxim , Iglauer Stefan 
Published: November 2017

Abstract
Nanofluids, liquid suspensions of nanoparticles (NPs) dispersed in deionized (DI) water, brine, or surfactant micelles, have become a promising solution for many industrial applications including enhanced oil recovery (EOR) and carbon geostorage. At ambient conditions, nanoparticles can effectively alter the wettability of the strongly oil-wet rocks to water-wet. However, the reservoir conditions present the greatest challenge for the success of this application at the field scale. In this work, the performance of anionic surfactant-silica nanoparticle formulation on wettability alteration of oil-wet carbonate surface at reservoir conditions was investigated. A high-pressure temperature vessel was used to apply nano-modification of oil-wet calcite sample at subsurface conditions (20 MPa, and 70°C). Moreover, to simulate all the potential scenarios inside the oil reservoirs, various concentrations of nanoparticles, surfactant, and salinities were tested. Contact angle measurements on calcite substrates and spontaneous imbibition test on limestone cores were performed to both the natural and modified (oil-wet) samples to consider the effect of heterogeneity and rock complexity on surface wettability. The results showed that formulations of Sodium Dodecylsulfate-silica nanoparticles can alter the wettability of oil-wet calcite to strongly water-wet at reservoir conditions. Further, the spontaneous imbibition data confirmed the role of nano-suspension to render the oil-wet pores to intermediate and water-wet.
The findings of this study provide new insights into nanofluids applications for enhanced oil recovery and carbon geo-storage.
Extensive Application of ESP with Permanent Magnet Motor: Continuous Improvement for Energy Saving and Cost Reduction
Authors: Hamzah Kamal , Prakoso Noke Fajar , Dwitiya Dipta , Kusuma Hendra , Amijaya Winandar , Yudhanto Geraldus , Bong Fendy , Hidayat Teguh , Wirasupena Harisza 
Published: November 2017

Abstract
Kaji-Semoga (KS) field, a mature field located in South-Sumatra, requires more efficient production operation to reduce production lifting cost. Since 2008, KS field has been experiencing gas shortage due to the decline in associate gas production. As a result, some of the gas lifted producer wells need to be converted to another type of Artificial Lift (AL). After various studies and trials, it was concluded that ESP (Electrical Submersible Pump) was the most suitable alternative. Currently, the AL system is dominated by ESP with total deployment 140 of 190 producing wells, contributing 70% to the field's overall oil production, i.e. a total of 9,500 BOPD. Furthermore, KS field purchases gas as fuel for the electricity system, which is mainly consumed by AL. Therefore, efforts have been made to evaluate and obtain significant cost reduction in power consumption of ESP through power efficiency assessment and feasibility of new technology implementation.
Power efficiency assessment for ESP application becomes a promising attempt to reduce ESP power consumption. Components which mostly affect the power consumptions are pumps and motors. With this understanding, technology selection of ESP has been carefully determined to obtain significant result in power efficiency. Permanent Magnet Motor (PMM) is one of the ESP technologies that offers higher efficiency, higher power factor, greater power density and wider operating speed compared to conventional induction motor (IM). Short term field trial PMM ESP application has been conducted. Field-testing procedures and measurements on power consumption are presented both for PMM and existing IM at identical condition (head generated, motor rating, pump type & fluid rate). It yielded conclusive result that PMM has higher power efficiency. Thus, a wider application is justified and expected to have substantial energy savings and cost reductions.
Currently, PMM is utilized at 20% of ESP wells in KS field. Field observation of these PMM-ESP units revealed power efficiency improvements by as much as 10-30% compared to IM ESP units. This improvement has led to the reduction of fuel gas consumption, which we have estimated to potentially save the company almost $ 750,000 per year in power generation expenditure. In the future, all IM ESP are planned to be replaced by PMM to gain higher cost reduction.
Identification of Hot Spot and Reliable Maximum Flow Rate by Production Logging for Sustainable Sand-Control Equipment Protection
Authors: Kim DongKyoon , Kim USU , Lee JungHwan , Sur YoungBin , Song JaeHak , Park JooSeon 
Published: November 2017

Abstract
This paper presents how to identify a hotspot, i.e. the most critical interval with a localized high gas rate and to determine the reliable maximum gas flow rate by interpreting production logging and calculating the fluid velocity at completion screen. This reliable characterization is highly important to prevent any failure of cased-hole gravel pack screens from fine particles.
Generally, operators manage the gas well within allowable pressure draw down range. The rule of thumb for restriction on maximum recommended drawdown ranged from 500 psi to 1000 psi. However wells completed through sand control equipment completion might encounter sand face completion failure in the occurrence of extremely high velocity flowing hotspot zone near the screen or liner. Therefore it is necessary to pay close attention to the detection of hotspot zone using production logging interpretation. Moreover, calculation of the maximum gas rate based on gas velocity profile through the screen would determine the allowable maximum flow rate with advanced method.
Normally In field cases, gas velocity higher than 1ft/s at the screen is considered as potential fluid velocity which could cause possible completion failure due to screen erosion accompanied by fine particles. One of the gas producing wells in SHWE project operated by Posco-Daewoo at Myanmar offshore, shows moderate mechanical skin damage and heterogeneous flow profile at the screen. Therefore rather than applying general drawdown criteria, calculating gas velocity at screen is recommended. To investigate the velocity profile at well bore, Production Logging was applied to Well-1 at SHWE field. By interpreting the Production logging, a highly biased flow profile was found out and reservoir interval showing highly biased flow would be suspected as of a hotspot zone.
Production logging interpretation results indicate that the flow rate of 500 psig drawdown is much higher than the flow rate correspondent of 1ft/sec velocity at hotspot zone due to highly biased flow profile. In this case, the general drawdown criteria will not guarantee the sustainable maintenance of screen however exposes potential erosion to screen. Therefore, the gas wells suspected to have biased flow profile required to detect any potential hotspot areas and should be operated with advanced criteria to prevent potential sand face completion failure.
Operations Management Dashboards: A Production Life Cycle Management Study
Authors: Fatnani Ashish , Nwachukwu Joseph , Makhmoor Felor 
Published: November 2017

Abstract
Efficiently managing the performance of sizeable onshore assets can be challenging, particularly in the absence of well-defined processes and technology to help organize people and data. This often leads to suboptimal processes, ineffective use of resources and time, and missed opportunities. Significant variations in producing reservoirs, artificial lift types, storage and processing facility capacity, data quality and availability, and even manpower can create varied operations and operational issues between areas (Farid et al. 2007). To help mitigate these challenges, an independent oil company and a service company collaborated on an integrated operations center (IOC) analytics dashboard called the operations management dashboard (OMD).
The independent oil company produces and operates in US onshore assets, which necessitates personnel working under complex operating conditions, using multiple applications, and processing data that are fragmented across these applications. The OMD integrated 17 different data sources from various areas, implemented multiple engineering logic calculations, and created intelligent real-time alarms to identify specific operational issues and facilitate asset management. This integration was performed on a single platform. The OMD leveraged solution capabilities range from displaying information from multiple real-time and historical data sources available across the field to streamlining business processes. This helps enhance field staff communications and support the company's management by exception philosophy, focusing on cases that deviate from the norm.
The OMD was deployed in one of the independent operator's onshore assets that included 1,000+ tank batteries, 7,000+ wells, and 20+ fields. The OMD automated processes helped reduce errors, resulting in less downtime and associated operational expenditure (OPEX). The OMD also standardized data analysis by allowing access to both historical and real-time data in a single workflow. Additional benefits were improved tank logistics resulting from tank level monitoring and timely and effective communication resulting from displayed work orders and comments between field and office personnel. Overall, the OMD facilitated access to consistent and in-context information, which was necessary for accurate and timely decision-making.
The dashboard's easy configuration, alerting functionality with the capability of defining meaningful and complex real-time alarms, and automated processes combined with easy-to-analyze visualizations proved valuable and resulted in enhanced decision-making. By defining alarms and automating processes, the OMD can help optimize injection gas rates during gas lift operations, identify mechanical lift issues, schedule field maintenance or inspections, and recognize production anomalies. The OMD can help quickly identify operational issues and production optimization opportunities. Additionally, it is expected to reduce downtime by 25% and decrease OPEX by 25%.
The Impact of Field Measurements, Data Handling Procedures and Software Selection on Carbonate and Sulphide Scale Predictions
Authors: Verri Giulia , Sorbie K. S. 
Published: November 2017

Abstract
Carbonate and sulphide scales are directly linked together and differ from other inorganic scales because they are intimately linked to the in-situ concentrations of CO2 and H2S, which influence the local pH and availability of reactive species. In previous publications, we described a rigorous workflow (step-by-step procedure) to accurately predict carbonate and sulphide scaling profiles from reservoir to separator using commonly available field data (Verri et al., 2017a). Although the workflow we describe is rigorous, the numerical results produced are of course subject to errors of different types.
In the present paper we identify and describe three key categories of data and procedures that must be correctly gathered and used in order to obtain accurate carbonate and sulphide scale predictions: these relate to field measurements, data handling procedures, choice of software, model equations and parameters. Moreover, in this work we estimate the impact of unreliable field measurements on the final carbonate and sulphide scaling profiles, with particular focus on gas and water chemistry errors. By varying important parameters such as gas phase CO2 and H2S concentration, water pH and alkalinity, Ca2+ and Fe2+ levels, we assess the impact that errors in these measurements could have on the final scale prediction profiles.
This work presents a comprehensive and systematic description of the common errors and challenges associated with the prediction of pH dependent scales (CaCO3, FeS, FeCO3). Moreover, the impact of various parameters on the final scale prediction results is established to distinguish between critical and non-critical data input in PVT and scale prediction software. The results from our analysis suggest that field measurement errors may not play a big role in high scaling risk scenarios, but that they are moreimportant in low/medium scaling systems. In addition, our calculations demonstrate the impact of increasing H2S on calcium carbonate scaling profile, which has not been previously addressed in the literature.
Breaking Produced Emulsions of an Alkaline Surfactant Polymer Flood
Authors: White Alan , Kaiser Anton 
Published: November 2017

Abstract
During the application of chemical enhanced oil recovery (C-EOR) floods, breakthrough of the injection chemicals periodically occurs resulting in stable emulsions. It is generally challenging to predict exactly when chemical breakthrough will occur, and flood designs try to eliminate this unwanted event from occurring. Some EOR recommendations use a combination of surfactant and polymer (SP), alkaline, surfactant and polymer (ASP), and variations on these two themes. In the event of chemical breakthrough, it is critical to have processes in place that can handle the ever changing conditions that evolve during the course of crude oil recovery. The emulsions from such floods can yield both stable water-in-oil (normal) and oil-in-water (reverse) emulsions particularly if the return of injection chemicals is higher than expected.
Chemical flooding involves injection of a predetermined volume of alkaline, surfactant and/or polymeric chemicals into the reservoir, in order to enhance oil recovery through reduction of Residual Oil Saturation (ROS) and enhancing sweep efficiency of the system. The surfactant, with its Interfacial Tension (IFT) reduction effects, reduces the ROS of the system, and the polymer, through its mobility control effects, increases sweep efficiency. Alkali protects the surfactant from being adsorbed, and also supplements the IFT reduction process, through saponification of the natural acids in the oil. ASP flooding has proved to increase oil recovery in many field trials globally. Several ASP pilots of different scales are reported to have yielded net incremental recovery factors in the range of 15% to 25% over waterflooding.
All physical factors listed previously that enhance oil recovery, can also greatly contribute to the formation of very stable emulsions which are ultimately quite different from naturally occurring emulsions which tend to be stabilized by components such as asphaltenes and resins. Traditional emulsion breakers are often not effective on emulsions created by chemical floods. Like any emulsion, these induced (i.e. basically synthetic) EOR-based emulsions need to be resolved or broken. Producing dry oil and clean water are requirements that all producers must achieve. Dry oil is needed to meet pipeline and various other transportation specifications, whilst clean water is required to meet environment regulations and operators’ own production needs.
The following paper focuses on an ASP pilot project in a mature Oilfield in Asia from the initial bottle test selection work through to field trial of the recommended Breaker chemistries.