bluuebunny/crossref_metadata_2025_split huggingface dataset:
Experiência hermenêutica. Um estudo sobre a possibilidade do conhecimento da revelação
Authors: Venancio Silvana 
Published: May 2016

Resumo: A revelação não é um corpo de verdades que caem prontas do céu, como um “ditado”, mas como uma realidade existencial. Não há experiência puramente “objetiva”, neutra e não-interpretada. Não se pode vivenciar uma experiência sem que de algum modo ela seja conceitualizada, exteriorizada e expressa pela linguagem ou por outro modo qualquer. Como a categoria de experiência é fundamental para se entender o significado da revelação, o artigo se detém sobre os fundamentos epistemológicos da experiência e o seu significado para a revelação. Palavras-chave: Revelação. Experiência. Conhecimento e Revelação. Abstract: Revelation isn’t a group of truths that comes to human beings without mediations. Revelation is an existential reality. There is no objective, neuter and not interpreted experience. It isn’t possible to have an experience without it be conceptualized, exteriorized and expressed by language or any other mean. Since experience is a fundamental category for understanding Revelation, this paper deals with the epistemological grounds of experience and its meaning for Revelation.Keywords: Revelation. Experience. Knowledge and Revelation.
A manifestação do sagrado no espaço do Convento da Penha
Authors: Gomes Helder Januário da Silva 
Published: May 2016

Resumo: O presente artigo apresenta os processos de manifestação do sagrado no espaço do Convento da Penha, localizado em Vila Velha - ES. Os símbolos religiosos que constituem a fé dos devotos em Nossa Senhora da Penha foram compondo historicamente diversos lugares e paisagens para a manifestação do sagrado. As contribuições desta discussão, no âmbito das ciências da religião, estão em utilizar os subsídios da geografia cultural, as questões espaciais como meios para problematizar, pesquisar e compreender os processos de manifestações do sagrado, ou a hierofania no espaço do Convento da Penha.Palavras-chave: Sagrado. Símbolos Religiosos. Convento da Penha.Abstract: This paper deals with the manifestation of the Sacred at Penha Convent, Vila Velha – ES. The religious symbols constitute the Faith of the Faithful and they compound historically places and landscapes for this manifestation of the Sacred. So, this paper is based on the contributions of the cultural geography and space questions as a way to problematize, to research and to understand the process of manifestation of the Sacred, or hierophany, at Penha Convent.Keywords: Sacred, Religious Symbols, Penha Convent.
O Processo de Morte na História de José o Carpinteiro
Authors: Gross Eduardo 
Published: May 2016

Resumo: O presente texto analisa o apócrifo História de José o Carpinteiro a partir da descrição do processo de morte que este apresenta, traçando para isto paralelos com as fases por que passam pacientes terminais conforme retratadas por Elisabeth Kübler-Ross. Palavras-chave: Morte, José o carpinteiro, Kübler-Ross.Abstract: The present text analyses the apocriphal History of Joseph the Carpenter from the viewpoint of the description of the death process presented by it; in order to do that, it traces parallels with the phases through which terminal patients pass, as they are described by Elisabeth Kübler-Ross. Keywords: Death, Joseph the carpenter, Kübler-Ross.
A comunhão trinitária como fundamento da ação missionário-pastoral das igrejas cristãs junto às tribos urbanas de rosto underground
Authors: Brotto Julio Cezar de Paula 
Published: May 2016

Resumo: Este artigo pretende apresentar a Comunhão Trinitária como fundamento missionário-pastoral para as Igrejas Cristãs diante do desafio eclesial denominado de tribos urbanas de rosto underground. Propõe que as Igrejas Cristãs que estiverem motivadas pelo fundamento da Comunhão Trinitária, pela demonstração de três valores relacionados ao Deus tri-unitário, abrirão um canal comunicacional para falar do Deus Cristão para as pessoas de vivência nas tribos urbanas de rosto underground. Os valores, solidariedade, compaixão e diálogo, presentes na Comunhão Trinitária são imprescindíveis para as Igrejas Cristãs como fundamento de uma ação missionário-pastoral que pretenda apresentar Deus e ofereça a proposta de vivenciar um cristianismo maduro em ambiente urbano de rosto underground.Palavras-chave: Tribos Urbanas. Underground. Comunhão Trinitária. Abstract: This article presents the Trinitarian Communion as the foundation for the missionary-pastoral action for the Christian Churches challenged by the underground urban tribes. It proposes that the Christian Churches must be motivated by Foundation of Trinitarian Communion and demonstration of the three values related to tri-unit God will open a communicational channel for talking about the Christian God for underground urban tribes people. The values, solidarity, compassion and dialogue present in the Trinitarian Communion are essential to the Christian Churches in support of a missionary-pastoral action that intends to present God and offer the proposal to experience a mature Christianity in urban underground environment.Keywords: Urban Tribes. Underground. Trinitarian Communion.
Stiff Targets Raise the Bar and Brings About a Game-Changer
Authors: Hussain Iqbal , Rasheed Al Enezi Dakhil , Sulaiman Sulaiman , Hayat Sara 
Published: May 2016

Abstract
Enhance Production by 100,000 bbls/day; Optimize and sustain Production rate by reduction in Water-cut; Drill over 100 Horizontal and Sub-Horizontal wells to increase production by over 1000 bbls/day/well and Smart completion methods to delay water-cut and maximize oil recovery. These objectives sounds straight out of the Management dream Wish-list to impress the stake-holders. Well, not so for Kuwait Oil Company.
These were indeed the objectives of recovering an aging field and creating a complete make-over of the fortune from this oil field in North of Kuwait. And as expected from all such grandiose projects, it did run into its own share of road blocks in achieving these objectives. Uncertain geological data, troublesome shale's cut at high angles, improper hole-cleaning practices, crew un-accustomed to handling challenges of horizontal wells and found wanting in many technical aspects, aging rigs finding it difficult to keep up to the demands of good hole cleaning and solids control, various short-coming of directional vendors and tools, completing wells with stiff ICD assemblies were the challenges which made the project stand the test of time and money.
KOC stood up to these challenges and devised strategies, practices and methods to overcome these crippling challenges. Wells which initially were completed in over 120 days were brought down through innovative solutions, state-of-art technology, sheer will-power and determination to succeed down to 45 days on an average. This paper is going to highlight optimizations, innovations and usage of cutting edge technology carried out to overcome these stiff challenges. The learning curve was steep but it was overcome with sharing of knowhow through team-work and the burning zeal to succeed.
This success story definitely holds lessons for all those who embark on the road to create magic. And this story definitely needs to be told over and over again.
Factors to Consider During the Pre-Screening Stage for Marginal Offshore Heavy Oil Field Production
Authors: Akuanyionwu Obinna Chiemezie , Solbakken Trond , Mackintosh John Mchale 
Published: May 2016

Abstract
Heavy oil reservoirs tend to be low energy, low GOR systems with high viscosities. These projects tend to have low recovery efficiency and low productivity compared to lighter oil. Offshore heavy oil projects typically produce a lower oil plateau with higher water production for longer periods of time and have higher capital and operating costs. As such these projects tend to sit at the bottom of any portfolio that contains light oil alternatives, with lower ROI, higher capital and operating costs.
These attributes impact the entire development, from appraisal through concept selection, development and operation. As such a different approach is needed to evaluate an offshore heavy oil field. Lateral thinking is required to reduce the capital and operational costs associated with a heavy oilfield with advances in technology solutions effectively driving the management of these challenges.
This paper discusses pertinent factors to consider and address during preliminary evaluation for marginal offshore field heavy oil production. These factors extend through many stages includingdevelopment concept selectionemulsion and viscosity challengesartificial lift selection and operational challengessand exclusion requirementsdrainage strategyscale formation challengespipeline transport considerations
To illustrate the main points, a conceptual case wherein the field-development concept is considered to be limited to a subsea tie-back to a host facility is presented. The applicable technologies and solutions (including the effects of diluent and the potential need for subsea multiphase pump boosting) considered necessary to meet a target production rate for this case are discussed. A modelling methodology as well as sensitivity analysis adopted to realistically investigate and underscore possible significant pitfalls and benefits within an integrated production-system network is equally highlighted.
Accounting for total production back-pressure effects may have significant implications for artificial lift design. The study also demonstrates the value that realistic pre-evaluation may add to the decision-making process for developing marginal offshore heavy oil fields.
Fracture Conductivity Calculation Using Mass Balance, Modeling, and Well Performance Data in Saudi Arabian Deep Gas Reservoirs
Authors: Rahim Zillur , Al-Anazi Hamoud , Al-Kanaan Adnan , Kayumov Rifat , Makmun Areiyando 
Published: May 2016

Abstract
The fracture conductivity values reported from the laboratory tests are based on ideal conditions and are usually higher than what actually contributes to production. In reality, the conductivity values are impaired by numerous factors in the reservoir such as high unconfined compressive strength, condensate dropout, proppant embedment, gel damage, etc., and cannot be fully captured in the laboratory measurements. The software models used by the industry to calculate fracture conductivity are specific to certain reservoirs, formations, and/or laboratory conditions and cannot be extrapolated or used for all reservoirs. In this paper, a workflow has been presented to compute fracture conductivity using various techniques and compare them to see what matches closest to reality in terms of well deliverability. First, fracture geometry and conductivity is computed using a mass balance and pressure match. Second, fracture conductivity is computed from the Cinco-Ley correlation and using industry software to estimate at static and dynamic well conditions using closure pressure, actual well performance, and bottomhole flowing pressure measurements. A range of fracture conductivity is computed during initial and later production periods by matching well rate and pressure behavior data. The calculations show the fracture conductivity achieved after a fracture treatment for specific reservoir conditions and how the values change during the production life of a well. Later, correlations relating to productivity increases with reservoir rock and pumping properties are used to optimize fracture treatments such that high rates can be achieved and sustained. The paper also presents different fracturing properties as functions of well productivity that can serve as guidelines for improved application of fracturing technology. Fracture conductivity is one of the most important parameters that impact post-fracture sustained production. Regardless of the formation permeability, higher conductivity values always assist in quicker fracture fluid cleanup and enhanced rate. There are a number of factors that affect the ultimate conductivity achieved in a fracture. They include fracture fluid gel and cross-linker loading, type and size of the proppant, proppant stages, concentration, and pumping sequence, and post-frac fluid cleanup efficiency.

Introduction
Hydraulic fracturing is being used in the Pre-Khuff sandstone reservoirs in Saudi Arabia to achieve higher sustained gas production and sand control in Saudi Arabian gas reservoirs1. The variability in reservoir properties in Pre-Khuff is significant with some areas that are extremely prolific where sanding becomes a major challenge with slight pressure drawdown while other areas that are tight with high compressive strength required long condictive fractures for commercial production.
Unlocking the Secrets of Seismic Anomalies in the Load Transfer Domain
Authors: Selnes Alsing , Edwards Alexander , Whitfield Neil , Waters Kester 
Published: May 2016

Introduction
We all know that temperature, pressure and gravity are the main controlling factors of rock properties and elastic properties in the sub-surface. The assumption of a constant gravity around the globe pretty much holds truth, while the other two factors, temperature and pressure, can vary significantly, even within a basin. This again will lead to wrong interpretations of AVO anomalies if not accounted for.
If we focus only on abnormal pressures in the sub-surface, the conception is that it is often associated with trouble; in an exploration sense, it could mean blown reservoir seals and misinterpreted AVO signatures (e.g. Shaker, 2009); for a driller, it could mean excessive time spent fighting formation fluid influxes and/or drilling fluid losses.
Overpressure detection is based on the premise that pore pressure affects compaction-dependent geophysical properties such as density, resistivity, and sonic velocity. Shales are the preferred lithology for pore pressure interpretation because they are more responsive to overpressure than most other rock types. They are also the most abundant of all rock types. Consequently, methods for overpressure detection center around shale deformation behaviour.
The essence of this paper will describe the importance of integration between elastic properties and pressure, and how to better understand and constrain AVO signatures. This is particularly true for how amplitudes in the load transfer domain (Lahann et al., 2011) may differ from what is expected at a given prospect level and thus may be overlooked as false negatives if not accounted for. This is particularly important in a regional context for exploration purposes (e.g. regional studies).

Overpressure mechanisms and elastic responses
The exact same conditions that control the sediments in the sub-surface in terms of elastic properties also control the geo-pressure side of things. A common approach for understanding AVO anomalies with increasing depth is by the use of depth trends (Figure 1) from well log data (Avseth et al., 2008; Japsen et al., 2007). However, one drawback with the common approach is that it only focuses on sands in terms of quartz cementation, and the chemical reactions that has a stiffening effect in shales, related to the smectite to illite (S-I) transformation and related disequilibrium compaction effects, but leaves out load transfer effects.
The same phenomena in shales is described by Thyberg et al. (2009), where Thyberg's assumptions (based on petrographic evidence and well logs) confirm an increase in both density and velocity when entering the chemical compaction window due to S-I diagenesis.
A Real Case of Integrated Multiphase Gathering System Optimization through a Flow Assurance Workflow
Authors: Di Sarra Andrea , Viadana Giorgio , Scaramellini Sara , Bianco Amalia , Masi Silvia 
Published: May 2016

Abstract
Production optimization is one of the most complex and multi-disciplinary task in the Oil & Gas industry. It involves the surface asset during all its production life and requires a continuous improvement process.
Integrated optimization of surface asset, including both gathering facilities and process plant, is a difficult goal to be achieved due to the complexity of such systems and the presence of several variables, uncertainties and operational constraints.
Technology improvements have enabled a widespread use of integrated simulation models for a better asset management according with actual field data.
Production department team of ENI E&P has developed a tool which maximizes production integrating gathering system simulation with process plant simulation. The global optimum is reached through a powerful genetic algorithm that, according to system constraints, allows to control different variables in a simultaneous way.
In fact, steady state simulation environments could bring to unstable field configuration. As a consequence, an updated operative workflow for fluid-dynamic module is needed. This workflow supports the process to select optimized solutions that do not have any criticalities during operation and asset variables upset. This implies that unstable solution are discarded among the investigated ones. Therefore, the obtained maximized production configuration is the global optimum solution (robustness of algorithm) as well as the most stable (fluid-dynamically).
Finally, multiphase transient code analysis allows to understand actual flow regime and, if necessary, to identify mitigative actions for management's improvement of investigated asset.
The integrated workflow has been applied to a real case study. This presents technical contributions of this work for definition of field potential, production optimization, de-bottlenecking activities, asset management.

Introduction
Oil and gas continue to be widely used worldwide as energy resources, because new sources of safe energy have not yet been well developed. These conditions have motivated researchers and workers in the area of oil and gas production to investigate new approaches in the application of optimization methods to maximize gas & oil production rates and to minimize production costs.
The term "Production Optimization" is used to describe different processes in the oil and gas industries. No rigorous definition has been found in the literature, but it means determination and implementation of optimum values of parameters in the production system to maximize hydrocarbon production rate and minimize operating costs under various technical and economical constraints.
Smart Fields - A Decade of Practice in Building Intelligent Fields and Collaboration
Authors: Chai Chon Fui , Van Den Berg Frans G , Engbers Peter 
Published: May 2016

Abstract
Over the past ten years, Shell's Smart Fields programme has built Intelligent Energy capabilities into key field developments and selected brownfields. The capabilities consist of new technologies and new ways of working, which are integrated to provide appropriate technical solutions for asset to become technology enabled from early phase of its development. The global deployment of these capabilities has led to considerable value to the business. New fields in development go through a screening at the early phase of the hydrocarbon maturation process, to identify intelligent energy capabilities valuable to each project.
High value has been achieved from solutions in production surveillance and optimization, smart wells, real time monitoring and optimization and time lapse reservoir surveillance. After some years of Smart Field implementation and value demonstration, the focus of the programme has shifted from "selling" individual solutions to achieving the "Appropriate Level of Smartness" (ALoS) in all key assets and projects.
Integration and new ways of working have been key drivers in the success achieved until now. Collaborative Work Environments (CWEs) have been implemented on a large scale, mostly focusing on the production and field surveillance area and on the real time monitoring. CWEs have improved the cooperation across the boundaries between disciplines and between office and field locations, enabling faster and better decision making. Strong focus has been placed on embedding the new ways of working into the organization. Business value is realized only if the adopted solutions and new ways of working are sustained.

1. Introduction
A Smart Field is an asset or group of assets that can be optimized continuously, managing both surface and subsurface aspects of the field through integrated models and workflows to maximize lifecycle value, while honoring existing operational constraints. This is achieved through an innovative integration of People, Processes and Technology. For more than a decade, Smart Fields has been identifying, developing and implementing integrated solutions that have become standard oil field practices such as Collaborative Work Environment, Smart Well, Reservoir Surveillance solutions in the areas of 4-D seismic and real-time production monitoring to name a few. To date the implementation of Smart Fields solutions have enabled the assets to increase production, reduce deferment, and improve ultimate recovery while reducing costs and HSSE exposure.
Hydraulic Fracturing Across Large Existing Perforated Interval Unlocks Reserves on Tight Sandstone Reservoir: Successful Workover Experience, Onshore Congo
Authors: Martocchia Francesco , Itoua Vignault Rolle , Farina Lisa , Baretti Salvatore , Martini Luca 
Published: May 2016

Abstract
When designing a hydraulic fracturing intervention, the selection of the interval to be perforated is critical in order to maximize oil production and to avoid unwanted gas/water breakthrough from neighboring layers.
While on new wells the perforation interval can be selected carefully analyzing logs and CBL, it can be challenging to design a workover where the HF targets a zone that is right in the middle of a large existing perforated interval (125 meters).
Leaving exposed too many perforations during a fracturing treatment could result in operational issues such as early screenout and/or uncertainties on the fracture initiation point. Zonal isolation could be obtained by cementing part of the perforations but this would mean in permanently losing part of the level.
This paper will describe a successful workover carried on a shut-in oil well, onshore Congo, where a single stage fracturing treatment was performed leaving exposed only few meters of the existing perforations and without permanently losing the remaining intervals.
This result was obtained using a multi-stage ball drop frac completion setting the packers across the perforated interval. The downhole equipment was able to withstand the treating pressure during the fracturing treatment and production was obtained through the frac sleeves.
This workover resulted in a significant oil production from a well that never produced until that moment.

Introduction
In the last decade, hydraulic fracturing has been widely used in Congo for the development of tight reservoirs: since 2007, more than 180 stages have been pumped on 9 different fields with almost one third of these jobs pumped offshore.
All of these treatments have been performed in a wide range of scenarios including: both sandstone and carbonate reservoirs, low to high temperature formations, field rejuvenation and exploration wells.
While applying this technology throughout the years, tailored solutions have been put in place to maximize oil recovery through frac design optimization. This learning curve included:Job design optimization (SPE 151860-MS)Fracture height detection (IPTC 16581-MS)Waterless fluids (IPTC 16640-MS)Completion Strategy and Operations (OTC 19455)Proppant flowback prevention (SPE 169959)
With the encouraging results obtained from the use of hydraulic fracturing, this technology has become the standard completion for tight reservoirs. When dealing with new wells, all aspects of well design, from well trajectory to perforation and completion strategy, are planned in order to optimize the hydraulic fracturing treatment.