bluuebunny/crossref_metadata_2025_split huggingface dataset:
Association of the salivary triggering receptor expressed on myeloid cells/its ligand peptidoglycan recognition protein 1 axis with oral inflammation in kidney disease
Authors: Nylund Karita M. , Ruokonen Hellevi , Sorsa Timo , Heikkinen Anna Maria , Meurman Jukka H. , Ortiz Fernanda , Tervahartiala Taina , Furuholm Jussi , Bostanci Nagihan 
Published: August 2017

AbstractBackgroundTriggering receptor expressed on myeloid cells (TREM‐1) is a cell‐surface receptor involved in amplification of inflammatory response to bacterial infections, along with its ligand peptidoglycan recognition protein 1 (PGLYRP1). TREM‐1 is shed by matrix metalloproteinases (MMPs) to its soluble (s) form. The aim of the study is to investigate association of sTREM‐1 and PGLYRP1 with oral inflammatory burden among patients with chronic kidney disease (CKD) at predialysis and posttransplantation stages.MethodsOne hundred forty‐four patients with CKD were examined at predialysis, and oral infection foci were treated prior to kidney transplantation. Fifty‐three patients were available for follow‐up after transplantation. Oral inflammatory burden was assessed by the Periodontal Inflammatory Burden Index (PIBI) and Total Dental Index. sTREM‐1, PGLYRP1, and interleukin (IL)‐1β were measured in saliva by enzyme‐linked immunosorbent assay, and MMP‐8 was measured by immunofluorometric assay.ResultsIn the predialysis stage, sTREM‐1 and PGLYRP1 were positively associated with IL‐1β, MMP‐8, and PIBI. More specifically, patients with deeper probing depth (PD) (at least two sites with ≥6 mm) had higher concentrations of salivary sTREM‐1 and PGLYRP1 compared with those with shallower PD. Higher concentrations of PGLYRP1 and IL‐1β were associated with a higher number of teeth (> 25). On follow‐up, higher PGLYRP1 and sTREM‐1 were associated with one or more sites with ≥4 mm PD.ConclusionssTREM‐1 and PGLYRP1 are elevated in patients with CKD with poor oral health and positively correlate with number of active periodontal pockets after oral infection therapy. Moreover, they positively correlate with MMP‐8 and IL‐1β. Hence, the salivary sTREM‐1/PGLYRP1 axis could be useful as a diagnostic marker for oral infection within patients with CKD.
A Fenomenologia e a formação humana na perspectiva de Edmund Husserl
Authors: SILVA CARLOS CARDOSO 
Published: August 2017

RESUMO:
O artigo discute a Fenomenologia e a Formação Humana na perspectiva de Edmund Husserl. É uma reflexão a partir do termo fenomenologia, onde procura compreensão do sentido e do significado do fenômeno, apontando que uma das principais preocupações da fenomenologia como método é evidenciar as estruturas em que a experiência ocorre, é deixar transparecer na descrição das experiências as suas estruturas universais. Apresenta as categorias de intencionalidade e epochê visando o conhecimento, onde todo ato de conhecimento (noema) corresponde a certa modalidade de consciência (noesis). Apresenta também, a categoria do Lebenswelt (o mundo-da-vida) fundamental e significativa para Husserl em toda a sua trajetória como homem e pesquisador rigoroso, discute a crise da humanidade europeia e a formação humana, uma contribuição para a educação problematizar os atuais problemas enfrentados pela humanidade.
PERFIL SOCIODEMOGRÁFICO DOS AGENTES COMUNITÁRIOS DE SAÚDE DA ESTRATÉGIA SAÚDE DA FAMÍLIA NO MUNICÍPIO DE PALMAS-TO
Authors: Alves Guimarães Maria Sortênia , Mucari Talita Buttarello , De Sousa Maria Fátima 
Published: August 2017

Resumo O Agente Comunitário de Saúde, nas duas últimas décadas, vem representando, no setor saúde, um profissional estratégico para aproximar as famílias e comunidades nos processos de trabalho em saúde. Entra em cena um novo ator político para contribuir no fortalecimento dos Sistemas Municipais de Saúde. Este artigo tem como objetivo traçar o perfil sociodemográfico desse profissional no Município de Palmas-TO. Trata-se de estudo tipo survey exploratório, realizada com 246 Agentes Comunitários de Saúde, entre janeiro e abril de 2014. A coleta de dados foi por questionários, em observância a Resolução nº466/2012 do Conselho Nacional de Saúde. Verificou-se que a maioria dos Agentes Comunitário de Saúde pertence ao gênero feminino (85,89%), está entre 30 e 44 anos de idade (68,57%) e apresenta ensino médio completo (54,06%). Dos 246 entrevistados, 38,21% fizeram cursos técnicos. Dentre esses 62,77% em Técnico de Agente Comunitário de Saúde. A maioria (55,19%) está na profissão entre 10 e 14,9 anos. O número de visitas domiciliares realizadas pelos Agentes Comunitário de Saúde foi em média 9,32 visitas/dia. Evidencia-se no estudo que o perfil que emerge da pesquisa é semelhante aqueles desenhado pela Política Nacional da Atenção Básica, ainda assim, destaca-se a necessidade de inserção dos mesmos em projetos de educação permanente.

Palavras-chave: Agente Comunitário de Saúde; Estratégia Saúde da Família; Comunidade.
A Pragmatic Approach to Managing Carbon Emissions in the North Sea
Authors: Stileman Tim 
Published: August 2017

Abstract
BP and other oil and gas companies have been engaged in efforts to address the risks and opportunities of global climate change for many years. Following the Paris Agreement of COP 21 in 2015 there has been a renewed focus and energy for action.
At the corporate level, integrated oil and gas companies, such as BP, are exploring options to reduce the carbon intensity of their products across the whole lifecycle to better prepare their businesses for a low-carbon future. Managing GHG emissions in upstream oil and gas production activities by improving efficiency and reducing flaring is one element of this.
This paper aims to highlight a pragmatic approach to managing carbon emissions from offshore installations operating on the UK Continental Shelf (UKCS) that helps maintain competitiveness and maximizes economic recovery in this mature basin. It does so by illustrating the key challenges and opportunities associated with managing carbon emissions in the UKCS.
The challenges are multiple and complex: Energy Intensity: Increasing energy consumption is required to maintain production from depleting reservoirs, and for new developments which often require pressure support and/or are from multiple small fields that deplete quickly.Plant Vulnerabilities: As equipment and infrastructure age the likelihood of failures increases leading to more frequent and potentially more challenging unplanned shutdowns and reduced plant reliability.Plant Optimisation: As reservoirs deplete topside plant design is often no longer optimized for production rates and well fluid compositions.Resource Constraints: Capital and offshore constraints such as bed space, or competing priorities such as safety critical maintenance, mean there are significant practical constraints which limit offshore maintenance and modification workscopes.Policy and Legislation: Can create incentives, through carbon pricing, which drive energy efficiency. However, in practice instruments such as the EUETS have not achieved this in the oil and gas sector. This is because EUETS rules do not recognize the unique characteristics of the offshore industry and because the carbon price has remained low for the last 5 years.
Despite the challenges there are opportunities to reduce and avoid emissions in the UKCS through: Operational efficiency: achieving stable, reliable plant by addressing the underlying causes of poor operational efficiency has great potential to reduce GHG emissions relative to production in the near term at no incremental cost.New technology: economic deployment of appropriate technologies on new and existing installations has the potential to reduce GHG emissions.
The benefits of pursuing these pragmatic opportunities include: Maximized economic recovery of hydrocarbonsReduced GHG emissions relative to productionLower exposure to carbon price under the EU ETS
Advancing The Application of Downhole Fibre Optics with a Novel Low Cost Disposable Deployment Method
Authors: Higginson Paul , Purkis Dan , Webster Michael 
Published: August 2017

Abstract
This paper will describe how fiber optics can be introduced into wells at very low cost, for the purposes of Distributed Temperature Sensing (DTS), using a novel disposable deployment method.
It was identified that the cost and risk associated with existing methods of installing fiber optics have. severely restricted the application of downhole distributing fiber-optic sensing. It’s because of this that technology has been developed that is cost effective enough to run in any well, resulting in a disposable system that uses the required materials to perform a singular operation.
The system utilises bare fiber optics, located in the tool, referred to as ‘dart’ herein. The fiber optic is de-spooled during free-fall deployment into the well. The system is disposed of in the well following the distributed sensing operation, which would typically only last several hours.
Tests performed in a shallow test well have shown that bare fiber optic can be successfully and reliably deployed into the well and that a Distributed Acoustic Sensing (DAS) survey can be performed on each fiber installed.
It was observed that the bare fiber was paid out into the well with no detectable slack, resulting in good depth correlation, important for determining the location of any event. It was also observed that the bare fiber attached itself to the inside of the tubing, which is thought to provide a good acoustic coupling - as well as a certain level of protection versus a freely moving fiber in the well.
It was concluded that the novel system is viable for use in oil and gas wells and would provide significant cost and risk reductions compared to existing methods of fiber deployment. The resulting increase in data from the application of such a system would have a considerable impact on production and well integrity, as well as offer vast cost savings in well abandonment operations.
The Sound of Silence: Innovative Approach to Confirm Barriers using Spectral Noise Logging
Authors: Ishmukhametova G. , Fokkema E. , Kelder O. , Rodger C. , Yurchenko A. 
Published: August 2017

Abstract
This paper details the deployment of Spectral Noise logging confirming barriers in a complex abandonment of an onshore field in the Netherlands to fulfil regulatory requirements and to support sustainable abandonment.
After initial plug and abandonment (P&A) activities on the main reservoirs, measurements showed pressure build up inside annuli. Spectral noise, high precision temperature and production logging were performed to determine the cause of sustained annulus pressure (SAP) and the location of leaks. The data acquisition was performed both under shut-in and pressure bleed-off conditions and both log responses were compared to identify changes in noise patterns. The noise from specific events such as channelling or reservoir activity was detected, so the abandonment program could remediate these issues successfully.
Application of spectral noise logging in this field yielded evidence that this technology can identify annulus flow for very minor build-up rates (0.1 bar/day). This paper further demonstrates the ability to allocate the SAP source behind multiple barriers and to validate plug integrity. It was observed that noise responses have a good correlation with ultrasonic cement evaluation logs aiding better understanding of the gas migration mechanism and change in noise patterns.
The temperature logging in most of the wells did not indicate any difference between shut-in and bleed-off regimes due to the very low leak rates. However, it did demonstrate the absence of any major cross-flow between formations. Insights in behind-casing flow geometry along the borehole helped to work out a remedial strategy to proceed with a sustainable abandonment of the logged wells.
For specific and complex cases, where conventional pressure monitoring and pressure test techniques cannot provide conclusive results, the spectral noise logging technology becomes a useful differentiator in selecting between possible scenarios during execution, The technology therefore brings significant value by reducing project cost without compromising the quality of the abandonment.
Significant Breakthrough in Shallow Reservoir Development
Authors: Grammeltvedt E. , Paraschiv M. , Worth P. , Hill R. , Brovko K. , Alexander G. , Boualleg R. , Piiparinen J. 
Published: August 2017

Abstract
Shallow oil reservoirs, commonly associated with heavy oil, require massive completion programs. The reason for these huge completion programs is due to the need for larger hole sizes compared with standard borehole developments.
The commercial feasibility of these developments relies on repetitive and predictable drilling performance in large hole sizes and high-angle curvatures to reach very soft formations.
One such development is the Mariner field in the UK sector of the North Sea, which was discovered 30 years ago. This field, located 140 km east of the Shetland Islands in 110m water depths, is the largest new field development in the UKCS. Two targeted reservoirs contain heavy oil in shallow unconsolidated sands in the Maureen and Heimdal formations.
Field objectives included the following:100+ well targets at the rate of ± 12 wells per yearTimely well delivery scheduleTechnology application to lower Drilling &Well operations sanctioned cost by at least 25%
The construction program for the Mariner field required the 20-in. casing shoe to be set at a shallow true vertical depth subsea (TVDSS) of ±750m, at inclinations between 35 and 55°, and build rates of 3 to 5°/30m in the ultra-soft formations with an unconfined compressive strength (UCS) of &lt; 1000 psi.
Although the advancements made in rotary steerable system (RSS) technologies are capable of generating 15 to 18°/30m dogleg severity (DLS) output, these technologies have historically been confined to small hole sizes extending from 5⅞ in. to 9½ in.
This paper describes the development of the world’s first RSS bottom hole assembly (BHA) design, capable of delivering repetitive and predictable performance to drill large hole sections to high inclinations in shallow, ultra-soft formations.
Say no to Pilot-Holes and Sidetracks - Mapping Complex Injectite Sand Reservoirs while Landing and from Inside - Case Studies from the Catcher Development
Authors: Roberts Stephen Kenyon , Riley Dominic , Gibson Matt , Nguyen Cuong , Martin Tom , Beck Andy , Bower Michael , Perna Ferdinando , Bisain Amarjit , Hui Xu Chong , Steele Joseph Wilding 
Published: August 2017

Abstract
As part of the planning for development drilling on the North Sea Catcher fields in 2015, Premier Oil sought technology solutions that would aid in drilling the complex injected sand reservoirs. Due to the highly variable and potentially discontinuous nature of injected and remobilized sand reservoirs, operators have historically had to drill multiple sidetracks and the utility of drilling pilot holes to reduce depth uncertainty was of particular concern. Pilot holes in injectite reservoirs have seen variable success, as the positional information obtained can only be extrapolated over short distances due to rapid changes in reservoir form and stratigraphic position. The complex 3D architecture of injectites also poses challenges in drilling horizontal wells, leading to difficulties in optimizing well placement, with an increased risk of having to carry out a geological sidetrack, and an increased risk of sidetrack failure due to missing reservoir or shale instability. Moreover, pilot holes and sidetracks come with their own drilling challenges, be it technical or financial.
To help de-risk these challenges, Premier Oil selected the Deep Directional Resistivity (DDR) logging while drilling tool to map and to help understand these complex injectite reservoirs. With a depth of investigation of up to and in excess of 30m (100ft) TVD from the wellbore, the service enabled the Premier Oil and Schlumberger Well Placement team to map the injectites complex external geometries and internal architectural features in real-time. Being able to resolve the form of the injectite reservoir in real-time provided the team the ability to use this wellbore-to-reservoir scale information to tie the position of the reservoir to the seismic data. From this it has been possible to forward project wellpaths and make informed geosteering decisions as wells drill ahead and new data is acquired. This ability to map and proactively geosteer, both on landing and within reservoirs in real-time, has helped Premier Oil to avoid both pilot holes and geological sidetracks.
In this paper three case studies are showcased. The first case demonstrates how the requirement of a pilot hole was eliminated by using the DDR technology. The second and third case studies illustrate the quantitative assessment of sidetrack risking and how data collected during drilling enabled optimum well placement via azimuthal geosteering and hence the avoidance of a possible sidetrack during the horizontal reservoir sections.
Precise Reservoir Navigation in a Highly Layered Reservoir, Cygnus, UK SNS
Authors: Dredge Ian , Simpkin Keren , Hart Nick , Watson Kim , Catto Ross , Kerr Adrian , Taggart Samantha , Gerick Eva , Wilding-Steele Joseph , Bisain Amarjit , Perna Ferdinando , Bower Mike 
Published: August 2017

Abstract
The Cygnus gas field is being developed by ENGIE E&P UK Limited in the UK Southern North Sea and is one of the largest discoveries in the Southern North Sea in the last 30 years. The field has two gas bearing reservoirs in the Carboniferous Lower Ketch Member of the Ketch Formation and the Permian Lower Leman sandstone. The Lower Leman Sandstone is the main reservoir target for 7 of the 10 wells in the development. The Lower Leman Sandstone is highly layered comprising fluvial influenced playa shoreline facies. The better reservoir quality intervals are restricted to thinly bedded laterally extensive sand rich intervals related to drier climatic events. Through utilization of reservoir navigation LWD tools the production wells have preferentially targeted these better quality thin intervals in order to maximize well productivity. To geosteer in these sands provided several challenges such as uncertainty in dip and the presence of sub-seismic faults. Furthermore the reservoir shows only subtle variations in log response from Gamma Ray and resistivity tools. This made correlations with offset well data difficult. As a result, the integration of information from multiple LWD tools and types of analysis was required to delineate the geological structure and to identify the stratigraphic position of the trajectory in order to place the well in the target interval. The key data sources for the leman productions wells have been the correlation to offset data, real-time Density images and utilization of Deep Directional Azimuthal Resistivity's. The limit of the Deep Directional Resistivity tool was tested due to the very low resistivity contrast reservoir (commonly 1-2 Ohm.m) but the data has still been utilized during geosteering operations. The quality of the density image data has also allowed for a real-time True Stratigraphic Thickness (TST) calculation service to be provided where extra stratigraphic control was required.
Five of the Leman production wells have been successfully drilled and completed with results that were at the high end of expectations. This will contribute to maximizing the productivity for the field.
In this paper the case studies showcased will demonstrate the Geosteering methodology utilized in this complex reservoir. For ENGIE, these examples demonstrate the value of investing in technologies for acquiring multiple data sets for successfully Geosteering in challenging geological settings.
Decommissioning Optimization in a Multi-Operator Landscape
Authors: Huijskes T. D. , Stoeller R. E. , Kreft E. , Ewijk E. T. , Langen C. T. , Scheffers B. C. , Mare G. W. , Bossers H. C. , Wolff M. H. , Vries G. G. 
Published: August 2017

Abstract
The oil and gas industry has brought significant benefits to the economy in the Netherlands. Not only from onshore fields such as Groningen, but also from the Dutch part of the Southern North Sea. Today about 700 offshore wells and 150 platforms still generate some EUR 2-3 billion revenues annually. In the coming decades production volumes and revenues will decrease while decommissioning and its associated costs are imminent. Total offshore decommissioning expenditures (abex) are significant, currently estimated at more than EUR 5 billion. This equals one-third of the total future offshore revenues.
EBN, the Dutch State participant in all offshore gas assets is responsible for about 40% of the decommissioning costs. EBN is investigating opportunities to reduce these costs without compromising HSE. Future decommissioning activities in the Dutch offshore are spread across three decades and 11 operators.
An optimization model has been developed to simulate the total decommissioning expenditures. The model consists of the complete Dutch offshore production network including wells, facilities, pipeline connections, gas production forecasts, operating expenditures (opex) and abex. Optimization is done on the total pre-tax Net Present Value (NPV). The model optimizes the timing of decommissioning of the offshore platforms and determines whether to produce at an annual loss while postponing decommissioning or to select early retirement. Two types of abex savings are implemented in the model: (A) capture and apply learnings from well abandonments within campaigns and (B) create large contract volumes (economies of scale) through joint decommissioning campaigns.
Several strategies may be beneficial, ranging from no or occasional collaboration to full collaboration strategies. This paper discusses the concepts applied and the results of several scenarios: (1) the reference case, (2) optimization within individual operator portfolios, (3) optimization of selected operator pairs, (4) cross operator collaboration, (5) all decommissioning by one decommissioning company. The results indicate that abex reductions could exceed 40% when all decommissioning activities are operated by a single dedicated decommissioning company.
The model presented is the first multi-operator offshore network optimization model considering decommissioning in the Netherlands. Input and boundary conditions are based on parameters which have been verified with a number of Dutch E&P operators.