bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development and Performance of Biodegradable Antiscalants for Oilfield Applications
Authors: Dickinson Wayne , Sanders Laura , Lowen Chris 
Published: May 2011

Abstract
Biodegradable scale inhibitors have been developed that provide excellent inhibition of barium sulfate scale and that meet regulatory requirements for application in the North Sea and in other sensitive marine environments. These inhibitors are in compliance with the " yellow-banded?? classification issued by the Norwegian sector of the North Sea, meeting ecotoxicity, bioaccumulation, and biodegradation standards. Using turbidity and dynamic tube-blocking protocol, the inhibitors have been shown to provide barium sulfate inhibition comparable to their non-biodegradable equivalents.

Introduction
Deposition of scale on production equipment impairs the production of oil and gas in reservoirs, down hole, surface and injection operations. Scale inhibitors are often a significant portion of the aqueous based chemical stimulation package used in either the stimulation and/or completion of oil/gas wells. Although highly effective, a number of the chemistries used for these applications-polyacrylates, polyphosphonates, and polysulphonates-have low biodegradability and are unable to meet increasingly strict environmental legislation.
A series of improved polymeric scale inhibitors have been developed in accord with the ecotoxicity, bioaccumulation, and biodegradablity standards set by the Convention for the Protection of the Marine Environment of the North-East Atlantic (OSPAR.. These inhibitors are highly effective for control of a variety of alkaline-earth scales and are suitable for use in scaling environments ranging from mild supersaturation to severe conditions where difficult-to-control barium sulfate scales may form. These products perform comparably to their non-biodegradable equivalents while exceeding the standards required for " yellow-banding?? status in oil production for the Norwegian sector of North Sea.
Basic polycarboxylic and sulphonated polycarboxylic acid chemistries were used as the basis of the new scale-inhibiting products. The new inhibitors were developed by examination of their scale inhibiting properties relative to conventional polycarboxylates and-in conjunction with biodegradation testing-were optimized with regard to scale inhibition, biodegradability, and price. Characteristics of the chemistries are shown in Table 1.
With the increased biodegradability and excellent scale inhibition performance of these range of chemistries, oil and gas producers can control scale in operations while meeting environmental requirements required in the North Sea and other locations around the world.

Experimental Details

Regulatory Testing
The regulatory requirements for ecotoxicological testing for all chemicals used for offshore drilling in the North Sea are specified in the OSPAR guidelines for the North-East Atlantic. These regulations were implemented in 2001 and are intended to harmonize the mandatory control systems for offshore chemicals. The three categories of tests required by OSPAR are:Acute toxicityBioaccumulationSeawater biodegradation (persistence)
Deviated Well Cross-well Elastic Wave Forward Modeling And Reverse Time Migration Imaging
Authors: Sun Yuan , Jin Qihu , Fan Tingen , Hu Shaohua , Yu Dai 
Published: May 2011

Abstract:
Deviated well is the widely-used drilling well for offshore oil exploration and exploitation is limited by platform. Besides, owing to limited lifetime of drill platforms, simultaneous extraction is popular in exploration, and reservoir's anisotropy problems show up. In order to solve problems like offshore deviated well cross-well seismic sampling design and wave field imaging, this article deduces finite difference equation of anisotropy medium staggered grid, and analyses anisotropy medium's numerical simulation questions in single source excited condition, and its border treatment adopts PML absorption border. On the basis of this, for fault model of deviated well, we adopt staggered grid finite difference reverse time migration imaging technology and do forward modeling and reverse time migration imaging on theoretical model. We have showed the validity of the arithmetic.

0 Introductions
In recent 20 years, no matter in theoretical methods or practical production, the resolution of cross-well seismic technology is much higher than that of the conventional ground seismic exploration technology in solving problems of fine structure imaging, reservoir and interlayer fine descriptions, reservoir dynamic monitoring and residual oil and gas predicting. Cross-well seismic technology has drawn extensive attentions in oil exploration and exploitation field, and has been developing rapidly. Concerning of region, onshore cross-well seismic has been replaced gradually by offshore cross-well seismic, and the observation method is changing from conventional vertical well to deviated well. However, during so many years of oil exploration, the change of cross-well reservoir is comparatively large and the anisotropy problem is typical. Always, there are certain problems when adopting conventional anisotropy medium model for forward modeling and wave field imaging. The purpose of this article is to solve the problem of offshore deviated-well cross-well seismic forward modeling and imaging.
Cascade and Chinook Project: Pipes and Bends: Material Design and Production
Authors: Novelli Paolo , Armengol Mariano , Darcis Philippe , Anelli Ettore , Fazackerley Bill , Kristiansen Per , Blockhus DJ 
Published: May 2011

Abstract
This paper describes the flowlines and hybrid risers' material selection and production for the Cascade and Chinook Development, a ground breaking ultra deep water project that will see the first production of the new Lower Tertiary in the Gulf of México.
The subsea development is very significant, given the number of records and firsts, resulting from the deepest production facility in the world, at the time, of 8,250 ft (2,520 m) and the deepest drill center at 8,857 ft (2,700 m) water depth. Production from the wells in Cascade East, Cascade West and Chinook will be gathered and transported to the FPSO (Floating Production, Storage and Offloading) via four 9 5/8?? flowlines and four FSHRs (Free Standing Hybrid Risers). A fifth FSHR connected to a 6?? gas export pipeline will take unused associated gas (gas that is not consumed on the FPSO) to existing pipeline infrastructure in Green Canyon.
The flowlines and riser systems included highly critical tubular components such as HW (Heavy Wall) pipes and bends, up to 1.63?? (41.4 mm), setting up a record in terms of metallurgical, production and dimensional requirements. This paper will provide details on pipe and bend selection and production, providing laboratory and manufacturing data, setting a reference point for future HPHT (High Pressure High Temperature) flowlines and risers' system development in the Lower Tertiary and in other critical deepwater developments worldwide.

Introduction
Cascade and Chinook fields are located in the Walker Ridge block, around 250 miles south of the Louisiana coastline in ultra deepwater, at around 8,500 ft (2,590 m) of water depth. Petrobras is the operator of both fields, with Total acting as a partner in Chinook field.
The Cascade and Chinook prospect belongs to what is defined as the Lower Tertiary Wilcox trend, a series of deep reservoirs discovered starting from 2001 in turbitide deposits ([1] Meyer et al., 2005). Besides the Cascade and Chinook fields, Lower Tertiary discoveries include Perdido folt belt, Great White, Jack and St. Malo prospect and the recent ultra deep discovery, Tiber.
Developments in Managing Flexible Risers and Pipelines, A Suppliers Perspective
Authors: Dahl Carsten S. , Andersen Bo Asp Moller , Gronne Mikael 
Published: May 2011

Abstract
With the increasing use of flexible pipe technology - driven by the move to deeper, more marginal and more challenging conditions - the need for systematic management of the flexible pipes is becoming more apparent. In particular, the full implementation of Riser Integrity Management (RIM) plays a vital role to ensure an efficient and safe operation.
This paper will discuss issues regarding Riser Integrity Management raised by operators and addressed to NKT Flexibles (NKTF) as the supplier. The discussion will include measurements and tests of flexible pipes, assessment and repair of possible damages, as well as assessment of change of regime e.g. change of location/ bore contents/ pressure/ temperature/ souring.
Riser condition monitoring and inspection form an important part of integrity management together with processing and analyses of the monitored data. The present paper identifies and discusses available and emerging options for condition monitoring and for engineering assessments and remedial actions, and discusses the recently developed technology of embedded optical fiber monitoring for quantifying the integrity of the flexible risers during their service life.

Introduction

Early Flexible Pipe Development
The development and use of flexible riser and pipeline technology for offshore oil and gas production is relatively young, however, flexible pipelines were applied for other purposes, before the introduction to the offshore industry.
The concept of a flexible armored marine pipeline was first introduced and applied at a significant scale in the World War II project codenamed PLUTO (PipeLine Under The Ocean) for transporting fuel under the British Channel from the United Kingdom to Normandy, France. The design was based on high voltage marine power cable technology.
The first commercial marine pipeline was installed between two Danish islands in 1964, also based on marine power cable technology.
The step on to high pressure pipelines, reinforced against collapse, for the offshore industry was taken in 1972, applying technologies developed by IFP, France.

Early Experiences
Initially, flexible pipelines have been considered maintenance free and not in need for regular inspection.
Since their first introduction, a vast number of improvements have been introduced to the design and manufacturing of the pipes, end-terminations and accessories.
Risk-Based Case Study of Floating Facility Drilling Riser Design Concepts in Deepwater Gulf of Mexico
Authors: Hull Meghan Eileen , Rees Jacqueline , Deegan Francis Jonathan , Botto Adriana , Whooley Alan 
Published: May 2011

Abstract
Regulatory changes in recent years have shown more stringent drilling riser inspection and maintenance criteria with the objective of minimizing Health, Safety and Environmental (HSE) risks, as evident with the December 2009 draft MMS NTL on integrity issues surrounding dedicated drilling risers used on floating production facilities. Additionally, the catastrophic Macondo incident has brought to the forefront the risks associated with traditional offshore drilling, which lends an added emphasis to clear assessment and management of HSE risks for all drilling and production risers.
This paper presents the methodology proposed for the risk-based comparison of different production and drilling riser system configurations. The methodology is recommended for the concept selection phase of any new drilling riser development to enable a side-by-side comparison of the critical risks within each system. This risk approach facilitates the identification of required mitigation measures to reduce risks to As Low As Reasonably Practical (ALARP). In addition an Integrity Management Strategy is proposed and recommended mitigation measures are compiled in different categories: design, inspection and operating measures. An action tracking database then assigns the implementation of mitigation measures to appropriate development phases (including the operations phase) to allow traceability and ensure risks remain ALARP.
The authors will demonstrate the implementation of this methodology for three drilling riser configurations: a monobore drilling riser (base case), a drilling riser with an insert casing riser system, and a monobore drilling riser with a Subsea Isolation Device (SID) system. The case study will consider a deepwater, normally pressured Gulf of Mexico field, taking into account the following scenarios: running the drilling riser; running of drill string and casing; drilling, before and in the hydrocarbon payzone; simultaneous operations (SIMOPs); and other vessel-related activities. Following typical practices for deepwater developments in the Gulf of Mexico, a surface blowout preventer (SBOP) is assumed to be employed for managing well control.
The insert riser system and the SID system will be considered by comparison to the monobore system to facilitate the presentation of each option. The most critical risks associated with all three drilling riser systems will be determined in a clear and transparent manner, along with the measures that are required to mitigate these risks to ALARP.
The Economics, Execution and Management of Complex Offshore Projects
Authors: Doherty Patricia 
Published: May 2011

Abstract
Macroeconomic trends, geopolitics, oil prices and the depletion of known hydrocarbon reserves are both motivating and compelling petrochemical companies to venture farther offshore in search of new supplies. And because most new hydrocarbon reservoirs are discovered in ultra-deep (upwards of 5000ft / 950m) remote waters, companies are faced with unprecedented physical, environmental, technical and project management challenges:–Physical environments are more hostile.–Exploration and production are more complex.–Environmental, technical, human and material risks are greater.–Capital expenditure and expected return on investment are higher.–Projects are more global and involve multiple stakeholders.–Contracts are more complicated.–Expertise is widely dispersed across a global ecosystem of specialized contractors, suppliers and partners.–Pressure to implement stricter governance standards and enhanced risk-response capability is increasing.–Investors seek to reduce time to first oil.
This paper examines:–The impact of macroeconomic trends, oil prices and geopolitics on offshore capital investment strategies.–The challenges program managers encounter when steering the planning, execution, governance, risk mitigation and delivery of projects involving thousands of globally dispersed multidiscipline participants.–How a collaborative project management model underpinned by state-of-the-art technology can provide secure on-line access to a single source of information, enabling a globally dispersed project ecosystem create, collaborate and share information seamlessly while protecting Intellectual Property (IP)—from Front End Engineering and Design (FEED) to platform construction, assembly configuration, and commissioning.–How dynamically updated performance dashboards provide a unique and reliable basis for risk mitigation, issue handling, prompt decision-making and enhanced risk-response capability.–How all stakeholders reap measurable benefits and valuable time otherwise spent collating unreliable information from disparate systems can be used on high-value management activities that have a direct impact on the economic outcome of a project.
It concludes that the time has come for companies to make a paradigm shift away from inefficient, adversarial, proprietary, stove-piped information systems toward the use of integrated collaborative applications that foster partnership and trust while protecting Intellectual Property (IP) and enabling equitable sharing of risks and rewards.
Reducing The Financial Impact of E&P Shutdowns
Authors: Dickey Lynn , Flesch Carlos Eduardo , Jordan Jonathan D. , Inacio Fernando 
Published: May 2011

Abstract
E&P shutdowns have a significant effect on business and operations, the former because of the production losses incurred while the platform is out of service and the latter because the amount of work completed drives future shutdown needs. This paper quantifies this effect and presents research that demonstrates the statistical correlation between the quality of shutdown planning and shutdown durations and predictability. Offshore shutdowns that reach the best level of planning have, on average, 40 percent shorter durations than those with the worst planning; only 12 percent of offshore turnarounds achieve Best planning, whereas 12 percent have poor planning. Actual observations are presented as case studies to clarify the research results.

Introduction
All shutdowns have an immediate negative financial impact because they result in lost or deferred production, although in the long run production typically increases as a result of the work done during the downtime. The negative impact is particularly true of offshore shutdowns because of the high value of crude oil and natural gas. Yet it is impossible to eliminate shutdowns because they are required to perform most replacement work, capital project installations, and legally required inspections. Given these facts, the best one can do is to employ those practices that will ensure the most efficient and the most predictable duration, while not compromising safety.
Research indicates that a strong correlation exists between certain specific practices and shutdown outcomes. For more than a decade, we have been testing hypotheses related to the correlation of various practices with shutdown outcomes and, for the last five years, we have included offshore shutdowns in the database. In addition, we provide lessons learned and case studies from various shutdown evaluations that we have completed.
The purpose of this paper is to share some of these findings to enable shorter, more predictable shutdowns and lessen their financial impact.

Research Methodology
The research is based on a shutdown database developed and maintained by Independent Project Analysis, Inc. This database consists of over 375 shutdowns, some analyzed at up to three different stages of planning development. Each shutdown in the database is characterized by more than 1,000 variables that describe in detail the shutdown's planning, execution, and process performance. The offshore shutdowns represented in the database come from locations around the world, as shown in Figure 1.
Development of New Generation Collar for J-lay Heavy Pipeline Installation
Authors: Salome Peter , Karjadi Erwan , Kleijne Elgar 
Published: May 2011

Abstract
J-lay collars are a safe and reliable way to install very heavy pipelines. In order to increase cost effectiveness and enable better quality control of the collar piece, a new concept of collar is proposed. The collar will contain multiple rims. The novel concept includes the total hang off load to be shared between two or more rims. This allows for a significant reduction of the overall wall thickness of the collar, which in turn provides opportunities for use of thick walled pipe, improved quality assurance as well as operational advantages with respect to weldability, transport over rollers and field joint coating.

Introduction
Heerema Marine Contractors has been installing deep water pipelines with Deepwater Construction Vessel Balder since it was converted to suit pipeline installation in 2001. The pipelay system on this vessel has a J-lay configuration. In a production line on the deck of the vessel, double joints are welded in a horizontal orientation into hex joints with a length of roughly 73 meters. The hex joint is then upended into a pipelay tower. In the tower the hex joint is welded in a more or less vertical orientation to the already installed pipe string. During welding, the suspended pipe string is supported by a hang off table. After welding, field joint coating is applied and the pipe string including the added hex joint is lowered towards the sea bed along the tower. During lowering the pipe string is supported by a head clamp on the travelling block in the tower. The hang off table and head clamp are fitted with pads suitable for the axial load and OD of the pipeline being installed. Figure 1 shows a pipeline just after lowering onto the hang off table. The travelling block is opening and about ready to travel back upward into the tower.
Economics of Pricing the Cost of Carbon Dioxide Restrictions in the Production of Electricity
Authors: Brito Dagobert L. , Curl Robert F. 
Published: May 2011

We calculate the cost of a carbon dioxide constraint in the production of electricity by modeling the replacement of coal generators with natural gas generators. We find: First, replacing coal generators with natural gas generators is the most economical way to reduce carbon dioxide emissions by 20 percent. Second, replacing existing coal generation capacity with modern coal generation plants can only reduce total carbon dioxide by 5 percent. Third, the distribution of the efficiency of coal generators in the United States restricts the range over which carbon dioxide prices effectively manage the displacement of coal by gas. Fourth, the narrow range for the price of carbon dioxide creates the possibility that a market in carbon dioxide permits will result in high volatility in the market for electricity. Fifth, the carbon prices implied by the transition from coal to gas will have very little impact on transportation fuels. doi: 10.5547/ISSN0195-6574-EJ-Vol32-No4-1
Psychological Distress Among Nurses Caring for Victims of War in Sri Lanka
Authors: Jayawardene Wasantha , YoussefAgha Ahmed , LaJoie Scott , Torabi Mohammad 
Published: May 2011

AbstractObjectiveTo determine prevalence and factors associated with psychological distress among nurses caring for war victims in Sri Lanka.MethodsDescriptive, cross-sectional study design was used to collect data from 241 nurses from 2 hospitals with stratified random sampling according to workstation. Self-administered 30-item General Health Questionnaire was used to detect psychological distress.ResultsThe prevalence of psychological distress was 21%. Female sex was found to be the most significant predictor of psychological distress among nurses. Factors, such as being married, having children, or both, were found to be protective. High exposure to war victims, measured by the frequency with which a nurse tended to those patients, also resulted in less psychological distress.ConclusionsThe prevalence of psychological distress is higheramong nurses in this study compared with that among the general population. Brief screening instruments, such as the General Health Questionnaire, can be used to identify individuals at risk for psychological distress. Results suggest that the presence of a social support network helped to psychologically buffer these nurses. Findings also imply the importance of promoting positive attitudes and beneficial stress (eustress) to complement a well-developed focus on distress prevention. (Disaster Med Public Health Preparedness. 2013;7:278-286)
What Variables Predict Quality of Text Notes and are Text Notes Related to Performance on Different Types of Tests?
Authors: Peverly Stephen T. , Sumowski James F. 
Published: May 2011

SummaryDespite the importance of notes to test performance, very little is known about the cognitive variables related to notetaking, especially text notes. The primary purpose of this study was to evaluate the contributions of transcription fluency, reading comprehension, verbal working memory, executive attention, and background knowledge to the quality of text notes. A secondary purpose was to evaluate the relationship of all of the other aforementioned variables to three test types to determine if notes are more important to some test types than others: a free recall essay and two types of multiple choice items: memory items and inference items. Results indicated that transcription fluency was the best predictor of notes (reading comprehension was also significant predictor), which extends previous findings on the importance of transcription fluency to lecture notes. Notes' were the best predictor of the essay and the memory multiple choice items but not the inference items. Copyright © 2011 John Wiley & Sons, Ltd.