bluuebunny/crossref_metadata_2025_split huggingface dataset:
Alcune considerazioni sugli eccessi dell’autocensura dell’impudico nella traduzione in rumeno del romanzo Venuto almondo di Margaret Mazzantini
Authors: Cosma Iulia 
Published: June 2014

Astratto
L’intento dell’articolo è quello di evidenziare gli effetti dell’autocensura del traduttore sulla lettura di un romanzo italiano contemporaneo, la cui versione in romeno è stata epurata dai termini licenziosi. Valutando come irrelevante la questione riguardante la motivazione del traduttore, lo scopo è quello di elencare e analizzare le notevoli differenze esistenti tra il testo originale e la sua versione in romeno, per rilevare e, di conseguenza, in un certo senso, annullare gli effetti di tale censura, rendendo giustizia alla scrittrice e alla sua opera.
Common Variants of cGKII/PRKG2 Are Not Associated with Gout Susceptibility
Authors: Sakiyama Masayuki , Matsuo Hirotaka , Chiba Toshinori , Nakayama Akiyoshi , Nakamura Takahiro , Shimizu Seiko , Morita Emi , Fukuda Nana , Nakashima Hiroshi , Sakurai Yutaka , Ichida Kimiyoshi , Shimizu Toru , Shinomiya Nariyoshi 
Published: June 2014

Objective.Recently, genetic analyses indicated the association between gout and cGMP-dependent protein kinase 2 (cGKII/PRKG2) gene in a Fukien-Taiwanese heritage population. However, no replication study has been reported in other ancestries. Therefore, we investigated this association in a Japanese population.Methods.Genotyping of 4 variants (rs11736177, rs10033237, rs7688672, and rs6837293) of cGKII was performed in 741 male gout patients and 1302 male controls.Results.cGKII variants have no association with gout.Conclusion.Our replication study suggests that cGKII is not involved in gout susceptibility.
Relationship Between Near Seafloor Seismic Amplitude, Impedance, and Soil Shear Strength PropertIes and Use in Prediction of Shallow Seated Slope Failure
Authors: Brand J. R. , Lanier D. L. , Berger W. J. , Kasch V. R. , Young A. G. 
Published: June 2014

Abstract
The movement of petroleum exploration and production to the frontier deepwater and ultra-deepwater of the Gulf of Mexico presents a variety of engineering challenges. One such challenge is the placement of seafloor production infrastructure on or near the base of steep slopes associated with the Sigsbee Escarpment. As a result, the potential hazards associated with shallow seated slope failures have become a legitimate concern. These types of failures can result in the formation of debris flows and turbidity currents capable of damaging or destroying seafloor structures in their path. The potential for significant damage or loss of seafloor facilities from such an event merits a comprehensive understanding of the factors that influence shallow slope failures. However, total field coverage with geotechnical cores to assess these factors is neither logistically or economically feasible nor practical. We present a new method for integrating these factors with available geotechnical core data and 3D seismic to quantitatively extrapolate and predict the location of critical areas of potential shallow seated slope failure.
GIS Based Analysis for Pipeline Protection Against Ice Gouging
Authors: King T. , Phillips R. , Barrett J. , Cuff A. 
Published: June 2014

Abstract
GIS-based software has been developed under the PIRAM (Pipeline Ice RiskAssessment and Mitigation) program for performing pipeline routing and burialanalysis for protection against ice keel gouging. Results are presented for ahypothetical pipeline in the Canadian Beaufort Sea. A probabilistic pipelineburial analysis is incorporated that accounts for the influence of sub-gougesoil displacements. Ice gouge rates and geometry are based on repetitivemapping survey data.
Natural Gas Hydrate (NGH) Arctic Ocean Potential Prospects and Resource Base
Authors: Max Michael  D. , Johnson Arthur H. 
Published: June 2014

Abstract
The compact Arctic Ocean region is the last major hydrocarbon frontier areain the Northern Hemisphere and may possibly be the single richest natural gashydrate (NGH) province on Earth. Because of the extreme weathering and erosionconditions associated with the alternating glacial and interglacial conditions, much of the sediment in accessible gas hydrate stability zones (GHSZ) may havethe same well bed-differentiated, coarse grained character of excellent NGHreservoir hosts. These reservoirs are of the same type that may hostconventional hydrocarbon deposits in more deeply buried sediments. Existingindustry exploration techniques have been used to identify potential NGHdrilling targets, and drilling in the northern Gulf of Mexico has validated theexploration technique. The Nankai deposits off SE Japan and the depositsdrilled in the northern Gulf of Mexico are excellent examples of thesand-turbidite continental margin paratype. It is estimated from examples andapplication of NGH petroleum system analysis that over 6,000 Tcf of natural gasin place may be present in NGH-enriched deepwater turbidite sands within deepcontinental shelf and slope sediments of the Arctic Ocean. In addition todeepwater turbidites, which are well known from other continental margin areas, such as the Gulf of Mexico, two other prospective zones may exist in the ArcticOcean. Troughs, which are glacially excavated depressions that generally deepentoward the shelf margins, may host NGH in sediments that are transitionalbetween the deepwater turbidites and continental shelf sedimentation. Concentrations of NGH may also be accessible from isolated outliers, which areupstanding continental crust fragments that are present within the Amerasia andEurasia Basins.
Application and Evaluation of a NanoFluid Containing NanoParticles for Asphaltenes Inhibition in Well CPSXL4
Authors: Zabala Romero Richard Disney , Acuna Hector M. , Cortes Farid , Patino Jose Edgar , Cespedes Chavarro Carolina , Mora Edgar , Botero Oscar Fabian , Guarin Liliana 
Published: June 2014

ABSTRACT
This paper describes the evaluation of a fluid containing nano-materials with high adsorption capacity for Asphaltenes inhibition in a volatile oil field in Colombia. Asphaltenes precipitation has been identified as one of the most potential damaging mechanism affecting the well productivity in Cupiagua Sur Field. Before this work traditional techniques have been tested in the field for asphaltenes inhibition. The goal of the injection of nano-fluids containing nano-particles of alumina with high surface area (&gt;120 m2/g) is to absorb the asphaltenes before being flocculated and carry them with the condensate avoiding precipitation near the well bore.
In the first stage of this work, lab testing, the adsorption capacity of alumina nano-particles for the asphaltenes produced in the field was evaluated, next, the nano-fluid containing nano-particles was evaluated in the Mirador formation plug cores by performing flowing core tests at the reservoir conditions. Returns of the relative permeability curves were quite good, improving Ko from 0,09 md to 6,13 md which enabled us to recommend the application of this nano-fluid in the well CPSXL4.
For the Field Application, the job was designed by forcing 220 bbl of nano-fluid within a radius of 8 ft. After the job, through monitoring with SARA analysis in produced fluids and the residual tracking of nano-particles as well. Maintenance of asphaltenes concentration in the produced fluids has been observed. Also, significant gain in the oil and gas production has been reported, with more than 100,000 bbls of cumulated gain production in only 4 months after the job was performed. Results may be promising and now it is possible to extend application of nano-fluid in other wells in this field.

INTRODUCTION
The Cupiagua Sur field is located 110 kilometers northeast of Bogota in the foothills of the eastern mountain chain of the Colombian Andes, close to other fields discovered in this area such as Floreña, Pauto, Volcanera, Recetor, Cupiagua and Cusiana (Fig. 1). Despite the fact that Cupiagua Sur is very close to Cupiagua, this reservoir is totally independent and separate. It is formed by a back thrust structure with several reservoir pressures, properties and contact fluids.
Cupiagua Sur is a compositional volatile oil reservoir with an average API gravity of 38°; there is no free gas cap at initial conditions. The main formations are Mirador and Barco which are quite similar about petrophysical and fluid properties (average permeability is 21 md and average porosity is 6.5%).
It is a prolific oil field that in fifteen years of production has recovered 88 MMstb gross out of 189 MMstb original in place from Mirador and Barco reservoirs in a developed area with four producer and two injector wells.
Comparison of Various Methods for the Assessment of Wind and Current Loads on a Semi-Submersible Platform
Authors: Croonenborghs E. , Sauder T. , Fouques S. , Reinholdtsen S.A. 
Published: June 2014

Abstract
The wind and current loads on a large semi-submersible platform were assessed using various methods by several participants. All participants treated the current and wind analyses separately. The current analyses were performed in a uniform flow. The wind analyses were performed in an atmospheric boundary layer flow. Flow angles ranging from 0 to 360 degrees were considered. Participants 1 and 2 performed wind tunnel tests on the same 1:250 scale model. Participant 3 performed steady-state full scale CFD simulations. Participant 4 performed towing tests (for the current loads only) on a 1:60 scale model. This paper presents, compares and discusses the results obtained with the different methods. The objective of this paper is to evaluate the variability which can be obtained in the results when using different validated and trusted approaches. The comparison shows significant discrepancies between the obtained wind and current loads. These discrepancies may be due to various aspects of the method setups such as the modeling of the atmospheric boundary layer flow, the scaling effects and the experimental uncertainty regarding the measurements.

Introduction
Wind and current loads contribute significantly to the total environmental loads on offshore structures. An accurate determination of those loads plays an important role in the assessment of e.g. stability and design of positioning systems. While underestimating the loads may lead to unacceptable safety margins, overestimation yields an inefficient design of offshore structures, e.g. a reduced deck load and costly design of positioning systems.
The flow patterns around the offshore platform are very complex. For accurate predictions of the wind and current loads, it is important that the assessment method includes a complete modeling of all the relevant physics. The traditional and most trusted method is based on wind tunnel tests on a scaled model. Towing tests also fulfill this requirement for current loads assessment. CFD simulations have also the potential to assess wind and current loads and are now recognized as a valid alternative to wind tunnel tests for analyzing flows around offshore structures. Independently of the method used, the loads must be determined in a carefully modeled environment.
In this study, four participants were asked to evaluate wind and current loads on a floating semi-submersible platform. The hull comprises a ring pontoon with six columns to support the topside. Participants 1 and 2 performed wind tunnel tests on the same 1:250 scale model. Participant 3 performed CFD simulations. Participant 4 performed towing tests (for the current loads only) on a 1:60 scale model. This paper presents, compares and discusses the results obtained by the four participants. The variability which can be obtained in the results when using different validated and trusted approaches is evaluated in this paper.
Establishment of Operational Criteria for Safe Launch of Free-Fall Lifeboats From a Turret-Moored FPSO
Authors: Fouques Sebastien , Croonenborghs E. , Aksnes Vegard , Luxcey Neil , Reinholdtsen Svein-Arne , Jokstad Cecilie 
Published: June 2014

Abstract
The evacuation of personnel from floating production, storage and offloading (FPSO) vessels in case of accidental scenarios is generally ensured by free-fall lifeboats launched from skids. Safe lifeboat launches occur for a specific range of pitch angles at water entry: flat water impacts may cause dangerous acconal criteria for safely launching the lifeboats. The importance of the wind velocity and direction with respect to the lifeboats is investigated. The study mainly focuses on the acceleration loads experienced by the passengers during water-entry and it is based on numerical simulations and model tests for the validation of the simulation tools and models.

Introduction
Free-fall lifeboats launched from skids constitute the primary means for evacuating FPSOs in sea states that do not permit helicopter landing, i.e. typically when the significant wave height Hs is larger than 5m. These lifeboats are generally installed at the bow of the FPSO at ca. 20m above the calm water level. The lifeboat launch is then influenced by environmental parameters such as the significant wave height Hs, the spectral peak period Tp and the 1-hour mean wind velocity Uw. In addition to environmental parameters, other factors like the heading strategy of the FPSO with respect to waves and wind, the loading conditions of the FPSO and the lifeboat, possible damage scenarios for the FPSO including loss of thrust or additional trim and list are also of significance.
The present paper is concerned with the establishment of operational criteria for safe launch of free-fall lifeboats from a turret-moored FPSO in the Norwegian Sea. The final goal is to estimate the probability of successful launch as a function of a selected set of the parameters listed above. So far, the main failure mode considered in this study has been possible human injury during water impact due to large accelerations. An example of quantity one aims to estimate is the conditional probability of being injured when seating in the aft seat row of a fully loaded lifeboat, if Hs is between 8 and 10 meters and the mean wind velocity Uw is larger than 20m/s. Provided a weather forecast, the obtained probabilistic model can then be used to decide if the lifeboats can be used in this sea state or if some seating restrictions have to be applied.
Maximizing Heavy Oil Production and Reserves Through a Multidisciplinary Well Construction Process
Authors: Haugen Vibeke Eilen Jensen , de Lima Claudio Jose Teixeira , Galletti Eduardo , Loures Luiz Geraldo Lucchesi 
Published: June 2014

Abstract
The paper discusses the aspects of the multi-disciplinary well construction process (WCP) that is being applied in the development of Peregrino field located offshore Brazil. Peregrino field is a heterogeneous sandstone reservoir containing a large volume of viscous oil in a complex depositional geological environment. The field development is based on a large number of long horizontal and multilateral wells equipped with high energy-demanding Electrical Submersible Pumps (ESP) for artificial lift.
The well construction process covers the feasibility, concept selection, detailed plan and execution phases. The efforts towards a multi-disciplinary process allow cost optimization, risk mitigation and production and reserves maximization. Multi-disciplinary teams include not only the usual subsurface disciplines (geophysics, geology, operations geology, petrophysics, reservoir and production technology) but also drilling, completion, topside and operations from an early stage.
In viscous oil fields it is especially important to meet the requirements in reservoir properties, well length and completion design to develop such a field economically. The applied WCP is allowing Peregrino field to achieve its goals in terms of numbers and quality of wells planned and drilled. More than 20 wells have been drilled so far with very good results. Peregrino is now producing at plateau production with a daily oil production potential of 100,000 bbl.

Introduction
Peregrino is currently the largest offshore heavy oil field in Brazil (14 ºAPI density and viscosities up to 400 cP) on production. The field is located in the southern part of Campos Basin, offshore Rio de Janeiro state (Figure 1). The reservoir lies between 2150 and 2350 m TVD MSL at a water depth of 120 m. Statoil is the operator (60%) with Sinochem as partner (40%).
Minimizing Scale Deposition Through Surface Enhancement in Downhole Tools
Authors: Graham Gordon Michael , Bezerra Maria Carmen Moreira , Goodwin Neil , Albino Eduardo Henrique , Pinto Hardy Leonardo , Bhavsar Rashmi B. 
Published: June 2014

Abstract
Inorganic scales are a significant production issue with extensive inorganic scales observed in many Brazilian offshore fields and is also a worldwide phenomenon resulting in considerable productivity impairment. With the intervention of more sophisticated downhole tools such as inflow control devices (ICDs) and inflow control valves (ICVs), increased shear stresses are experienced in the wellbores near these devices resulting in an increased risk of scale formation and adherence even under very mild levels of oversaturation. The impact of scaling on or near ICDs or ICVs will have a dramatic impact on productivity since scaling would form in the wellbore itself.
In this work we have focused on downhole carbonate scaling under Petrobras new deepwater field conditions where the drawdown in the near wellbore area results in oversaturated brine systems. Downhole conditions have been modeled and closely simulated in the laboratory to ensure that laboratory conditions closely match the mild level of over saturation expected due to drawdown such as the ones present in ICV orifices.
The work initially examines the relationship between increased shear and scaling examining both bulk scaling (homogeneous precipitation) as well as the relationship between shear and surface scaling. The results show that there is interdependence between bulk and surface precipitation as a function of increased shear. In addition the work examines a range of different materials of construction commonly used in ICVs including different metallurgies, and different surface finishes as well as coatings specifically designed to minimise the potential for scaling.
Work at a variety of shear conditions clearly shows the potential to minimise surface scaling by careful material selection and / or by the use of specially formulated surface coatings. A mock valve has also been designed and commissioned to allow testing of the potential for scaling under realistic downhole flow conditions at representative downhole temperatures and pressures. Preliminary work using this more representative " pilot" test design is also discussed.
Increasing Oil Recovery on the Grane Field With Challenging PWRI
Authors: Tipura Lejla , Tjomsland Tore , Fagerbakke Ann-Kristin 
Published: June 2014

Abstract
The G-32 well was the first PWRI (produced water re-injector) to be drilled into the Heimdal Formation at the Grane oil field, located in the Norwegian Sea. Reservoir simulations suggested that G-32 would improve reservoir drainage in the area, providing an important increase in oil recovery through the nearby oil producers. The well was planned as a matrix injector rather than a fractured injector to optimize the reservoir drainage. This gave challenges related to well cleanup and also required good water quality to avoid loss of injectivity by screen/formation plugging. A large effort was made in the preparation phase for G-32 to minimize the risk related to these issues and with the precautions taken, low risk of plugging and loss of injectivity was predicted. This paper will summarize the G-32 experience from both a production and a reservoir management point of view. Simulations and testing performed prior to starting up the G-32, including fracture simulations, produced water analysis, lab tests of the completion fluids and injection experience will be presented. Finally, expectations from the reservoir simulations performed prior to G-32 start-up will be discussed and compared with production experience.

Introduction
The Grane field is a mature oil field located about 185 km west of Haugesund, in the North Sea, Figure 1. It was discovered in 1991 and the field came on stream September 2003 with license to produce until 2030 (J.A. Haugan et al, OTC 18234). Oil is currently produced from 26 wells, 14 of them are multilaterals. Three injectors are drilled into the reservoir, two gas injectors and one water injector (G-32). Two water disposal wells are injecting water into the shallower Utsira Formation.
Aboriginal Engagement and Development of Northern Projects
Authors: Bosgoed Gary , Collett Blaine , Willier Dion 
Published: June 2014

Abstract
Positive and sustained relationships are essential to ensure successful project outcomes. In fact, according to Independent Project Analysis, an important best practice is an Integrated Project Team. The public attention to recent Oil Sands related projects in northern Canada is an example of the need for projects to effectively engage local communities early and to seek out opportunities to make all project stakeholders successful. Aboriginal communities are an often overlooked part of a project's execution plan and its long term success.
Success in remote locations means project objectives must be aligned with local cultures, traditions and social values. In the past, the economic benefits of a project were the primary driver of community alignment with development. Today economic development, while important, must align with the needs of Aboriginal societies. Because the underlying resource reserves are very large, project benefits may need to be realized over two or more generations.
An Aboriginal Engagement strategy has been developed and implemented with Aboriginal communities most affected by northern energy, mining and infrastructure development projects. A core part of this strategy is to have corporate values and policies committed to open, positive, long-term and sustainable relationships with Aboriginal communities most of whom in this paper are in northern Canada. This paper will discuss ways of effectively engaging Aboriginal communities to align their traditional and cultural lives with the socio economic benefits of northern development. This contributes to the ongoing well-being of the community over the life of the project.
Aboriginal Engagement must start well ahead of the project's Permit to Build. This facilitates appropriate engagement with Aboriginal communities to fully understand the traditions, culture and underlying social and economic structures so that subsequent agreements realize both community and corporate benefits, and to craft relationships respectful of both aboriginal and corporate values. In the case of large projects, a company may need to engage with several communities. Successes and progress in implementing this strategy will be covered, as will ongoing application of the process to adapt to unique community needs for others.
The numerous challenges faced by Aboriginal communities in the face of northern industrial development will be discussed, including the unique project opportunities afforded to them. Engagement and empowerment of Aboriginal youth through education and skills will also be covered in light of expected labor shortages, particularly in the construction industry.