bluuebunny/crossref_metadata_2025_split huggingface dataset:
EVIDENCIAÇÃO AMBIENTAL SOBRE RESÍDUOS NOS RELATÓRIOS DE SUSTENTABILIDADE DE EMPRESAS BRASILEIRAS LISTADAS NO IBrX-100 DA BM&FBOVESPA
Authors: Degenhart Larissa , Vogt Mara , Rosa Fabricia Silva da , Hein Nelson , Kaveski Itzhak David Simão 
Published: August 2015

<p><strong> </strong></p><p>O estudo objetivou analisar a evidenciação ambiental sobre resíduos nos Relatórios de Sustentabilidade de empresas brasileiras listadas no IBrX-100 da BM&amp;FBovespa. Para tanto, realizou-se uma pesquisa descritiva, documental e com abordagem quantitativa. A população do estudo constituiu-se de 100 empresas brasileiras listadas no IBrX-100 da BM&amp;FBovespa e a amostra compreendeu 25 empresas em 2010, 35 em 2011 e 45 em 2012, estas que divulgaram dados sobre resíduos em seus Relatórios de Sustentabilidade. O período de análise compreendeu os anos 2010 a 2012 e a análise foi realizada por meio de um <em>ranking </em>das empresas que mais aspectos evidenciam sobre resíduos em seus Relatórios de Sustentabilidade. Os resultados apontaram que as empresas Ambev, AES Tietê, Energias BR e Duratex foram as que mais se destacaram no <em>ranking</em> nos anos analisados. Além disso, na maioria das empresas o fator tipo de informação sobre resíduos sólidos e resíduos perigosos transportados foi apresentado nos relatórios na forma descritiva e quantitativa. Já em relação aos métodos de disposição, todas as empresas que lideraram o <em>ranking</em> possuem tratamento dos resíduos que produzem. Ainda, no que diz respeito às metas de redução, a maioria das empresas do <em>ranking</em> divulga que a meta de redução foi de 75% nos anos analisados.</p><p>Palavras-chave:<strong> </strong>Evidenciação ambiental. Resíduos. Empresas brasileiras.</p>
Determining The Optimal Frequency Of Carrying Out Well Integrity Tests
Authors: Farwana Amany , Taylor Ian 
Published: August 2015

Abstract
Three hydraulically actuated isolation valves are able to completely isolate flow from a producing well to prevent uncontrolled flow; these are the PWV (Production Wing Valve), PMV (Production Master Valve) and the SSSV (Subsurface Safety Valve).
As part of the drive for continued improvement in well safety, more prescriptive well integrity guidelines have been issued by the Oil and Gas UK. It is now recommended to test the safety critical isolation valves every six months unless reliability findings specific to the asset, valve type or location specify a different testing frequency. A documented rationale is therefore, required to either justify the current lower frequency of testing or accept the recommended frequency which could incur significant additional deferment and testing costs.
This paper outlines a novel method for quantifying risk using a Reliability Based Model (RBM). Actual data on valves' integrity and status, sourced from an electronic well integrity database, was used in the RBM to determine the probability that the valves will operate on demand. The availability of the valves was determined and quantitatively linked to a testing frequency that will ensure the reliability standards are met.
Using a calibrated risk graph, the RBM assumed a SIL 3 (a high target level of risk reduction) for an offshore platform well; equivalent to achieving a target availability in the range of 99.9 - 99.99%. The optimal testing programme was based on achieving a low SIL 3 rating due to the slow progression rate of the failures identified.
The RBM showed that only 25% of the wells studied required testing every 6 months. This demonstrates that by utilising specific asset data as outlined in the latest OGUK requirements, a more representative testing frequency can be determined which can potentially minimise deferment and maintenance costs.
Autonomous Routing Of Drilling Fluids Leads to Safer Operations. Experiences Gained On New Xle Jack-ups
Authors: Klemetsen Thomas , Hundebøl Henrik 
Published: August 2015

Abstract
This paper will detail how autonomous routing systems can make the transfer of drilling fluids faster, safer and more efficient than contemporary drilling fluid processing plants. It will use real-time data to show the benefit to drilling efficiency on three Maersk Xle Jack-Ups, while examining the potential for HSE improvements and cost savings gained through the increased safety measures inherent to the system.
Drilling fluid processing plants typically contain a large number of interconnected tanks, pipes, valves and pumps. These systems have very flexible routing possibilities for the chemical additives and drilling fluids within a limited footprint. However, they are vulnerable to accidental routing and mixing of chemicals due to a high degree of human involvement. Manual/remote manual systems are prone to human errors resulting in contaminations (e.g. mixture of oil based mud and water based mud), spillages, drilling down-time, and possibly well control incidents.
An autonomous routing system has been successfully deployed on three new and highly automated jackups. The system has been used on Maersk Intrepid with uninterrupted service since August 2014 and they have not experienced any spills due to wrong lineups. It has been used during all operations, on multiple wells and sections. From experience spills are an area of high focus during start-ups. On new builds, the crew needs to familiarize themselves with the new mud system and face a steep challenge to oversee a new piping/system; consequently drilling fluids could be routed incorrectly. The ability to line up several operations simultaneously has greatly improved efficiency and has shortened the learning curve for the crew during startup.
The routing system DORS acts similarly to a car navigation system in that it utilizes knowledge about the plant and real time data to find the most optimum route. In addition, it operates equipment automatically and reacts adaptively to changing conditions such as equipment failure(s). It supports simultaneous operations, always ensuring that no contamination occurs.
Girls In Energy STEM Programme
Authors: McCloskey Pádraig 
Published: August 2015

Abstract
The Girls in Energy course is an important part of Shell's STEM education programme; providing young women with the information and inspiration they need to pursue a career in the energy industry.

Meeting the needs of the industry and the business
Every year, the UK faces a shortfall of over 81,000 people with engineering skills. Between 2010-2020 Scotland will need to recruit 160,000 people with engineering skills. To meet this demand Scotland needs to increase the number of graduate and apprenticeship engineers.
To help meet the demand, we developed the Shell Engineering Scheme in 2002 to help recruitment Technicians for the St Fergus Gas Plant, in the North East of Scotland. The bespoke scheme delivers training that allows them to enter the energy sector. However, in 2009 we received no applications from females for the course. Recognising this needed to be addressed, we developed the Girls in Energy course with North East Scotland College (NESC) to encourage more females into the industry to meet the growing skills shortage.

Girls Energy
In 2010 we started the Shell Girls in Energy programme. It's a one year course, delivered by NESC, designed to open young women's eyes to the energy industry's wealth of career opportunities. It is targeted at girls aged 14–16 in secondary education, and when completed they will receive a (Scottish) National Qualification in Energy.
Before starting the programme many had thought that a job in the industry meant working on a platform in the middle of the North Sea. The course helps students to rethink these preconceptions and show them that there are a huge number of different careers available both offshore and onshore all over the world.
Girls in Energy pupils get to understand the future energy challenge including some of the pressing challenges we face in the world today and the role engineering plays in meeting the growing energy demand in a sustainable and innovative way.

A qualification in Energy
Tutors from NESC deliver weekly lessons, workshops and field visits; providing 160 hours of engaging STEM education over the year-long course. Participants that successfully complete the end of course assessment receive an Intermediate 2-level qualification in Energy, This qualification, which was introduced by the Scottish Government to encourage students to study new subjects, provides an excellent grounding for working in the energy industry.

The future
Shell is committed to increasing the pipeline of STEM professionals, especially among those groups, like women, that are under-represented in the energy industry. We are currently in discussions with Skills Development Scotland and Colleges Scotland about the best way to give more women the opportunity to learn about the value and opportunities available in the energy industry.
The Economics of EOR Schemes in the UK Continental Shelf (UKCS)
Authors: Kemp Alex , Stephen Linda 
Published: August 2015

Abstract
Enhanced oil recovery (EOR) schemes have been slow to evolve in the exploitation of hydrocarbons from the UK Continental Shelf. They are generally much more expensive to execute offshore than in onshore USA where they are relatively common. This paper provides a detailed analysis of the economic aspects of several EOR projects namely low salinity waterflood, polymer flood, and miscible gas injection. Detailed economic modelling of example schemes finds that, in current circumstances in the UKCS, prospective returns, while worthwhile in undiscounted cash flow terms, are only very modest at discount rates reflecting the cost of capital. It is also noted that there are several significant investment risks. Further tax incentives relating to the purchase of polymer and miscible gas could enhance returns to these EOR projects without introducing any distortions.
Advanced Well Failure Modelling Improves Well Integrity, Safety and Reliability
Authors: Girling Stuart , Snow Nigel , Lumbye Peter , Abdelhamid Ibrahim Abouelhamd 
Published: August 2015

Abstract
Well failure modelling uses pre-emptive risk assessment to address well integrity issues more effectively than risk assessing well barrier leaks and other integrity anomalies as they happen. Users of Well Failure Models (WFMs) benefit by spending less time doing risk assessments and achieve more consistent results; better understanding of well issues; more efficient well intervention planning and reduced well services costs; improved well reliability and thus reduced production losses and safer wells. By adopting a well failure model Maersk Oil Qatar rasies the bar with respect to HSE and management of their well integrity.
Development of a WFM utilises a what-if risk assessment for specific well types, characterised by service, flow capability, well pressure, architecture and various environmental considerations. Well component leaks, failure modes and other integrity anomalies are analysed. Corrective actions, severity codes and repair grace periods are established for each issue for all well types.
The Maersk Oil Qatar (MOQ) WFM has been in use since 2012. It considers failures and failure modes for all well barrier elements as well as preventative maintenance anomalies for the various well types in the Al-Shaheen field, offshore Qatar.
The 2012 WFM has grace periods based on the subjective judgement of experienced drilling and production staff, agreed in facilitated workshops. In 2014 work was initiated to upgrade the WFM using quantitative risk assessment (QRA) techniques to calculate grace periods.
This paper describes development and structure of the 2012 WFM. It also explains the QRA techniques used in the 2014 WFM upgrade and outlines the initial results obtained with both models. Currently MOQ are running the 2012 model and will soon begin to populate the 2014 QRA model with actual failure data in order to calibrate the model.
Reductions in risk exposure and improvements in risk management are the most important objectives MOQ expect to realise from this approach. Further to this there potentially are substantial financial benefits for Maersk through efficiency gains, cost saving and increased production volumes, this underpins the company goal of being a top quartile performing operator with high focus on safety.
Managing Ageing FPSO Structures: Effective Management of Inspection Data
Authors: MacLean Calum , Lewin Matthew 
Published: August 2015

Abstract
This paper explores the challenge of gathering, assessing and usefully managing large quantities of hull inspection data so that this can provide useful information. It will address assessment of the data to ensure that it is possible to clearly understand what is important today, what might be an issue tomorrow and to identify trends and evaluate inspection / repair burdens in the future.
As an FPSO hull structure ages, the routine structural inspection activities produce increasing volumes of data as time progresses. In the initial years of production this does not present a major issue to manage as the number of structural deficiencies will (hopefully) be small. Beyond 10 – 15 years on-station, where inspections are carried out there are often significant numbers of inspection findings reported (&gt;1500 per year).
It is important that data is captured accurately at the time of inspection, whilst the personnel and access are available. In the early years of asset life, where the number of findings may be only 1 or 2 per day of inspection, efficient handling of the data and assessment isn't a high priority. During busy inspection campaigns during the later life of the asset, good quality reporting and efficient data handling become critical factors as it is possible to have 3 inspection teams on an asset producing upwards of 60 inspection findings per day, 7 days per week. Failure to effectively keep up with the processing of the inspection findings under these conditions will result in inaccuracies in the data and a failure to correctly assess criticality and the necessary actions arising.
Based on Marine Technical Limits extensive experience of managing significant volumes of hull inspection data for various FPSOs over the previous 10 years, this paper will detail the key criteria and an effective approach for handling, processing, assessing and using hull inspection data to produce useful information.
Meeting the Demand for Barrier Plug Integrity Assurance
Authors: Stein Arild 
Published: August 2015

Abstract
When two wellbore barriers are set in close proximity it is difficult to determine if the upper barrier plug is holding pressure. Measuring the liquid volume pumped to achieve the pressure test does not always provide adequate assurance.
The wireless Barrier Verification System (BVS) was developed to meet the demand for barrier plug integrity assurance. The system consists of a pressure sensor with a transmitter attached below the barrier plug. A Receiver is mounted on top of the installation tool to wirelessly record the pressure measurements below the plug. An additional pressure sensor forms part of the receiver to provide an accurate reference pressure measurement above the plug.
The transmitter sends pressure readings and can record for multiple days depending on battery selection, wellbore temperature and logging frequency. The Receiver also records and stores the reference pressure information collected above and wirelessly from below the barrier plug.
For Slickline conveyance, the system will be configured for readout of the memory after the Receiver is retrieved. Real-time readout to surface is an option when used on E-line.
The wireless BVS system was first used in the Norwegian Continental Shelf (NCS), mounted on a 5.5″ Medium Expansion (ME) Retrievable Bridge Plug, and on an 3.5″ Electronic Setting Tool (EST).
Following the setting of the barrier plug, it was pressure tested from above. The graph showed a differential pressure across the barrier plug which verified and provided assurance that the plug was holding pressure (Pressure above ~ 450 Bar and pressure below ~ 230 bar).
Verification of Well Abandonment Barriers
Authors: Stein Arild 
Published: August 2015

Abstract
When setting two deep wellbore barriers in close proximity it can be difficult to be assured that the upper barrier has integrity. Only by measuring the pressure between the barriers can the integrity of the shallower barrier be verified.
Well abandonment practice is dictated by territory specific regulations which are largely based on historic practices. However, emerging technologies and methodologies are gradually changing the outlook, affecting the way we carry out future P&A operations.
With the introduction of any new methodology or technology there is a need for verification and testing of the permanent barrier. Currently, the typical concept is to use an anchoring or plug device to build a barrier above.
The wireless BVS (Barrier Verification System) uses ELF (Extreme Low Frequency) telemetry and has the capacity to transfer signals through the barrier or surrounding wellbore/lithology to a receiver above the established seal. The system consists of a pressure sensor with a transmitter attached below an anchoring device. A receiver is lowered on slickline or electric-wireline above the barrier to be tested. The receiver wirelessly records the pressure measurements transmitted from below the anchoring sealing device. An additional pressure sensor in the receiver forms part of the toolstring to provide an accurate pressure reference above the established barrier for verification testing.
The transmitter can record for multiple days depending on battery configuration, wellbore temperature and logging frequency. The receiver can transmit real time data or it can be deployed in memory mode for slickline, coiled tubing and pipe-deployment applications.
The objective of this paper is to examine and explore the technology of the BVS, the design and development, the qualification tests carried out, and the execution and results of an operation in the North Sea.
Competency – The Partnership Approach
Authors: Paley Carole 
Published: August 2015

Abstract
Competency - the Partnership Approach
Within Oil and Gas service companies, there is tension between developing medium to long-term capability and delivering the service clients demand. Balancing these two requirements is a continual challenge. Both employers and employees recognise a constant need to develop their skills and knowledge base, and an important requirement of an employer is to be astutely aware of their organisation's talent requirements. Employers must identify and acquire talent through recruitment or retraining, and once acquired, employees must be trained and developed to meet the specific business demands for the present and the future. The need to ensure the effectiveness and application of the knowledge transfer process is more important than ever, and has to be done by measuring the skills and knowledge of the individual through a structured competence programme. There are practical challenges of embedding a competency process within an international organisation and these will be explored in this paper.
In the past, the oil and gas industry placed a high premium on experience, which is by definition a reflection of time served. The rapidly changing needs of clients necessitate the acceleration of learning and development activity in the workplace, as the supply of experienced individuals does not always meet the demand. Therefore employers are required to obtain talent and accelerate the knowledge and skills of existing employees, ensuring that talent has been converted into a capability that adds value to the organisation and fulfils client needs by ensuring delivery of excellent service quality. Traditional competency measurement of skill and knowledge has been paper-based, and whilst effective, has proven to be both labour and time intensive when performed by assessors. An alternative approach is electronic competence measurement deployed via a learning management system that allows for electronic knowledge and skills assessment, reducing administration burden and the need for assessor intervention through the automatic recording of completions. If not skillfully managed the binary nature of this approach can limit the integrity and robustness of the system so it is imperative to ensure that additional measures are introduced to maintain and indeed enhance the assurance of the individual's competency.
This paper will discuss the cultural, geographical and technological challenges encountered and how they were resolved during the development of a global competency-based system, in an international service company. The paper will propose a | number of innovative methods to address the issues encountered when incorporating a global electronic competency system, whilst maintaining its on-going integrity.
Driving Production Efficiency Improvement on the UKCS: Implementation of the PETF Strategies
Authors: Dornan R. , Werngren O. , Wyllie B. 
Published: August 2015

Abstract
A significant decline in industry average Production Efficiency was observed on the UK Continental Shelf between 2004 and 2012, with a decrease from 80% to 60%. This decline led to the formation of the PETF in June 2013 to address this issue, with the target of restoring PE to 80% by 2016 being set by government and industry. Since 2012 PE has increased from 60% to 65%, which has contributed towards the stabalisation of production volumes on the UK Continental Shelf. This paper will investigate the drivers of the decline in Production Efficiency and outline the initiatives being implemented by the PETF to facilitate a basin wide improvement, including driving improvements in planned maintenance shutdowns, excellence in offshore productivity and reducing unplanned production losses.
Assessment of Casing and Annular Material in Heavy Mud Weight Systems and Thick Pipes - Case Study
Authors: Cristancho Diana , Susanto Indriaty , Singh Kamaljeet , McCann Chris 
Published: August 2015

Abstract
There has been an increased recognition in recent years of the importance of acquiring logs for casing corrosion and annular barrier evaluation for well integrity purposes. It has been a challenge to acquire data in High Pressure and High Temperature (HPHT) environments, where thick pipes and heavy mud weight systems are commonly encountered.
In the past, the mud weight had to be decreased or mud changed to evaluate the casing integrity and cement placement, costing extensive time and money. However, recent developments in ultrasonic tools have enabled the acquisition of logs in these difficult environments.
This paper describes the logging tool advances for cement evaluation and annular material characterization. It shows, through a case study, how advanced ultrasonic technology enabled the evaluation of the cement and annular material placement for the abandonment operations of an HPHT well in the North Sea. The challenging characteristics of this well are thick casing (0.672in) and heavy mud weight (14.9ppg OBM). A workflow was designed, from planning to execution, to ensure a successful logging job; thereby optimizing the project cost. The log results from advanced ultrasonic technology are discussed and a comparison of the data with the previous generation tool is made. The applied use of data is discussed to plan and optimize the well abandonment program.