bluuebunny/crossref_metadata_2025_split huggingface dataset:
Editorial: How to Review Scientific Manuscripts and Clinical Case Reports for Journal of Oral Implantology
Authors: Rutkowski James L. , Cairone Joseph V. 
Published: December 2009

Abstract
Peer review is a vital component of the publication process for the Journal of Oral Implantology (JOI), as with any scientific or professional journal. The ability to write constructive critical reviews, therefore, is a valued skill of benefit to authors, editors, and the journal. The purpose of this article is to discuss techniques for crafting useful reviews. A review should address both broad issues of wording and perception. A review should include specific issues of what to look for in each section of research papers and clinical case reports. While the article is written with JOI in mind, most guidelines expressed therein are applicable to reviewing for any journal.
Effective use of Production Surveillance Tool in Forecasting Future Production
Authors: Aderemi Samuel , Akpara Kingsley 
Published: December 2009

Abstract
Decline curve analysis is a graphical procedure used for analyzing declining production rates, and forecasting future performance of oil and gas wells. This is achieved by curve fitting the past production performance using the rate-time data and extrapolating it to predict future performance, with the primary aim of estimating reservoir remaining reserves and/or remaining productive life.
The effective use of the forecast techniques: Empirical, Fetkovich, Locke & Sawyer, and Analytical Transient solutions for oil and gas wells/Reservoirs, using a production surveillance tool that manages multi-wells effectively in less time is discussed. The last three techniques-type-curves require good understanding of the reservoir model as well as the parameters controlling the well behaviour. To effectively use any of these techniques for forecasting future production, it is imperative to determine the dominant flow regime from the production data.
This paper focuses on concepts that enable engineers determine the dominant flow regime from diagnostic plots generated from rate-time data and/or numerical iterative method. Once we are able to establish the dominant flow regime, we can now decide which of these techniques to be used.
Finally, the concepts were applied to field rate-time data.
An Experimental Investigation on the Impact of Capillary Pressure, Diffusion Osmosis, and Chemical Osmosis on the Stability and Reservoir Hydrocarbon Capacity of Shales
Authors: Al-Bazali Talal M. , Zhang Jianguo , Chenevert Martin E. , Sharma Mukul M. 
Published: December 2009

Abstract
Wellbore instability in shales is the most challenging and costly issue in drilling operations. Wellbore instability in shales can be attributed to many factors some of which have been well studied and documented. However, the physicochemical and mechanical properties alterations in shales which eventually leads to wellbore failure have been largely ignored. Water and ions movement in and out of shales plays a major role in the alteration of the physicochemical and mechanical properties of shales thus leading to wellbore instability problems and possible hole collapse. Water and ions can move in and out of shales by many mechanisms including, but not limited to, diffusion osmosis, chemical osmosis convective flow and capillary suction.
This work presents experimental data analyzing the impact of chemical osmosis, and diffusion osmosis on water and ion movement when shale interacts with drilling fluids. The adopted experimental work minimized the effect of convective flow and capillary suction. Results show that water movement is not only controlled by chemical osmosis (water activity) as previously thought, but is also influenced by diffusion osmosis. This insight provides information and guidelines to optimize drilling fluids to effectively control and mitigate wellbore instability when drilling through troublesome shale.
Furthermore, pressure transmission tests were used to experimentally measure capillary entry pressures of various non-wetting fluids (oil-based mud, crude oil and Nitrogen gas) through shales. These capillary entry pressures are needed for the estimation of shales seal capacity (h).
Fluid Identification Challenges in the Near Critical Fluids: Case Studies in Malaysia
Authors: Kyi Ko Ko , Yahaya Norfadilah , Daungkaew Saifon , Hademi Noor Rohaellizza , Cheong Boon , Mohd Azam Mohd Nor Hisham , Yusuf Nora , Sinnappu Suresh , Anh Do Quoc , Wong Surianee Bt Rosli , Nguyen Hai Minh 
Published: December 2009

AbstractReservoir fluid identification plays a crucial role in reservoir characterization and hydrocarbon volume estimation. Gas condensate reservoir is well known for its complex behaviour due to the nature of a near critical fluid. The reservoir pressure and temperature in such reservoirs are very close to the critical point, and therefore, small changes in reservoir condition will result in a change of fluid properties considerably. As a result, there exists a broad spectrum of reservoir fluids in this reservoir condition.Identifying reservoir fluid in the zones of interest is extremely challenging, especially when it is associated with overpressured low porosity shaly sandstone reservoir. It becomes difficult and at times impossible to definitively identify different types of formation fluids from the well logs alone. This paper presents challenges of fluid identification process during the exploration/appraisal campaign in such reservoirs, offshore Malaysia, where the operator needs to gather as much information and as quickly as possible to make immediate operation decisions and Field Development Plans (FDP).First part of this paper demonstrates an integration of available data including mud logs, gas chromatography, gas wetness ratio, well logs, formation pressure and DST in order to determine fluid types in a well where an expected reservoir fluid is oil. The result from a systematic integrated reservoir characterization performed later, however, has found that the reservoir fluid is gas condensate.The second part shows an extensive application of Downhole Fluid Analyzer (DFA) in the Wireline Formation Tester (WFT) tool to conclusively identify reservoir fluid types and their properties in-situ and in real time in the second well drilled in a different fault block. In this case, the use of WFT together with DFA has allowed identification and PVT property determination of a full range of downhole fluids including gas, retrograde gas, volatile oil and black oil. This suggests a number of compartments in such complex reservoirs.
A Generalized Predictive Control for Management of an Intelligent Well's Downhole, Interval Control Valves—Design and Practical Implementation
Authors: Yang Qing , Davies D. R. 
Published: December 2009

Abstract
This paper presents an advanced control method for online regulation of downhole Interval Control Valves (ICVs) to achieve optimal production via choke performance management. A Generalized Predictive Controller (GPC) has been shown to be capable of automatically controlling the area open to flow of multiple ICVs to achieve a specified production rate. A black box model was established using real-time, downhole, instrument data as a predictive model for the controller. The model parameters were updated in real-time using the Decay Recursive Least Squares (DRLS) method. A case study in which a multi-zone horizontal intelligent well was located in complex reservoir showed that the GPC operation is highly effective. The robustness of the technique was illustrated by its ability to operate effectively in the complex reservoir environment when the signal is perturbed by outliers or by random noise levels up to the control error limits. The value of these control error limits must be increased as the step size of each valve operation becomes larger.
Offshore Diving Safety—Challenges and Concerns
Authors: Sherman Chris 
Published: December 2009

Abstract
Commercial diving in the North Sea was once viewed as the ultimate example of a highly paid but very dangerous occupation. Regulation (both external and internal) and many hard lessons have resulted in great improvements in training, equipment and procedures. Diving is undoubtedly much safer than it was 30 years ago, but it remains one of the most hazardous activities in the offshore industry.
The paper will identify a number of challenges facing the offshore diving industry - some of which give cause for concern. For example, the sector continues to enjoy a worldwide boom which has resulted in a severe shortage of experienced divers, supervisors, support personnel and diving support vessels. These shortages are likely to worsen in the coming year, despite record numbers of divers passing through the diving schools and the ongoing construction of diving vessels and diving systems. The age profile of the offshore diving workforce (and much of the equipment in use) is likely to further exacerbate these problems.
Over the last 2 years, there has been a significant increase in diving related Dangerous Occurrences (near misses) reported to the United Kingdom's Health & Safety Executive (HSE). These include a number of incidents that could have resulted in fatalities or serious injuries. This situation is not limited to the North Sea and there have been a number of serious accidents reported from around the world. The paper will explore this trend. The paper will conclude that most diving accidents are not "new" and that the lessons from the past must not be forgotten. While adherence to current regulations and industry standards is generally the best way to reduce risks to acceptable levels, some new thinking may now be needed in areas such as training and competence assessment.
An Overview to Applicability of Multilateral Drilling in the Middle East Fields
Authors: Paiaman Abouzar Mirzaei , Moghadasi J. 
Published: December 2009

AbstractThere are several types of drilling methods to increase the productivity of a well, such as horizontal drilling, extended reach horizontal drilling and Multilateral (ML) drilling. It is thought that ML wells could be more economic with higher productivities than horizontal or extended reach horizontal wells. Advances in ML drilling promise reduced costs, greater flexibility and increased profit potential.In the last 20 years, thousands of ML wells have been drilled worldwide, but only a small percentage of the total number of wells is multilateral. The probable reason may be lack of concise information and misconceptions surrounding the costs and perceived risks. However, recent advances in the capabilities of the systems and applications have proved ML drilling to be a truly revolutionary and cost effective solution for the industry.This paper investigates the benefits of ML drilling as one of the highly expanded methods. Moreover, advantages, challenges, and priorities of the ML technology are highlighted. Since application of ML wells requires some improvement and development especially in the Middle East, therefore, two case studies from this region are presented. The first case study is the first Saudi Aramco's deep ML gas well, and the second is drilling a dual lateral well in Dukhan field in Qatar. For the first case study, productivity of ML wells is presented. Furthermore, a comparison is made between the productivity of a horizontal and dual ML in order to give a recommendation for one of them.
Jura Fast Track Project
Authors: Lesgent Jérôme , MacIntosh Jimmy , Simons Phil 
Published: December 2009

Abstract
This paper focuses on Total E&P UK strategy for the fast track development of the Jura Project and resultant challenges encompassing: ▪Contract strategy to maximise schedule efficiency and flexibility.▪Innovative design engineering for subsea application: –First use worldwide of subsea chemical injection metering.–Subsea hard HIPPS IL 3 rated with fibre optic control, first Subsea HIPPS in the Total Group.▪Bundle construction utilising controlled depth tow method with the heaviest ever installed lead towhead.▪Towhead design with multiple diver/ROV retrievable components (including complete piping and control modules).▪Adapting design and strategy to capture base parameter changes - addition of second well to project during main contract Tender negotiations.

Results/Conclusions
Dissertation on the challenges faced and overcome to deliver the Jura project: ▪Multiple contractors / vendors directly managed by Total E&P UK at diverse locations (USA, Germany, France, Holland, Norway, Ireland and UK multiple locations).▪Technical solutions achieved - HIPPS, Chemical Injection, and Towhead design.▪Logistical innovation for towhead transportation.
Development of a Thin Low Permeability Gas Field With Spiralling Dual Lateral Horizontal Wells: The Halfdan Northeast Field
Authors: Christiansen L. B. , Jeppesen M. W. , van Lingen P. , Rod M. H. 
Published: December 2009

Abstract
The Halfdan Northeast gas accumulation was discovered in 1968 and comprises a low permeability chalk of the Ekofisk formation. The thin reservoir interval has an effective permeability of about 1 mD in the best parts, segmented vertically by cm-thick layers of extreme low permeability and considerable lateral extent. As a result, the productivity is relatively poor. To overcome the challenges presented by the tight chalk reservoir, a stepwise approach to field development has been applied. Maximum reservoir exposure obtained in the most cost effective manner was from the beginning identified as a pre-requisite for a commercially attractive development.
The first development phase in 2004 comprised three long reach horizontal wells drilled from the nearby Halfdan field. These wells enabled early development of the gas utilising existing facilities. During this phase it was realised that despite reservoir sections of 15,000 ft production rates were disappointing.
Two long dual lateral wells were drilled during the second development phase showing that a doubling of the reservoir section could be achieved at 1.6 times the cost of a single lateral well while productivity increased proportionally with reservoir exposure.
An ambitious third development phase was planned with 6 dual and 2 single lateral wells covering the eastern part of the field. The wells were planned in a spiralling pattern which provides a uniform coverage of a large area in comparison with the traditional radiating well pattern. To date, 8 of the planned wells have been successfully drilled.
As a result of several novel ideas to maximise reservoir exposure while minimising costs, the development of the thin Ekofisk reservoir in the Halfdan Northeast field is well underway and production in line with expectations.
Safety Leadership: A View of the Senior Managers' Role
Authors: Roger I. , Flin R. , Mearns K. , Hetherington C. 
Published: December 2009

Abstract
Senior managers have been described as a ‘neglected species’ in safety research, yet their influence on organisational performance is frequently examined in relation to productivity and financial success. The Energy Institute is now sponsoring a research project on senior managers' safety leadership in the oil and gas industry. This paper presents early findings from a series of interviews with senior managers and safety experts from within the energy sector. The paper explores whether particular leadership styles influence senior managers' ability to promote safety within their organisations. Descriptions of effective safety leaders consistently included elements of transformational leadership, supporting findings from previous research. The interviews also revealed that elements of authentic leadership appear to be particularly crucial for safety leadership from the senior management level.
Exploring the Resource Potential of a Dormant Deepwater Tight Gas Condensate Accumulation Using Modern Seismic Technology—The Spanish Point Discovery, Main Porcupine Basin, Offshore Ireland
Authors: Pugliese S. G. , Davies D. J. , O'Sullivan J. M. 
Published: December 2009

Abstract
The Spanish Point gas condensate discovery is located in the Main Porcupine Basin, approximately 150 km off the west coast of Ireland in water depths of 300–400 m. The discovery well, which was drilled in 1981 by Phillips Petroleum, is situated near the crest of a number of NE–SW trending rotated fault blocks and encountered a gross c. 400 m hydrocarbon–bearing interval in a series of stacked over–pressured Upper Jurassic deep–water gravity flow sands. Drill stem testing yielded rates of 4.85 MMscf/D and 925 BOPD from the shallowest of four logged hydrocarbon–bearing intervals at a depth of c. 4,000 m. Individual sandstone units are medium to thick bedded with average sandstone units of 50 m which are separated by shales of the Kimmeridge Clay Formation. The well test data imply relatively low permeabilities (generally &lt;1 mD), which may be due to the presence of clay minerals within the sands, or to secondary hydrothermal alteration as a result of local igneous intrusions. The latest geological model, which is based on modern rock–physics and seismic inversion has significantly increased the potential resource base and suggests a median un–risked recoverable contingent resource of 1.4 Tcf and 160 MMBO. Whilst the Spanish Point discovery is primarily a structural trap, mapping of its northern extent indicates that the spill point may be shallower than the gas–down–to seen in the 35/8–2 discovery well. This observation, together with the over– pressured reservoir regime, which is not seen in wells further to the north, raises the possibility of a stratigraphic component to the trapping mechanism. A 3D seismic survey acquisition programme is planned for 2009, which aims to further enhance our understanding of this accumulation as well as being of use for positioning of any potential future appraisal well locations.
Cost Effective Deepwater Well Construction - A Case for Managed Pressure Drilling with Casing
Authors: Oyeneyin M. Babs 
Published: December 2009

Abstract
Engineers now face increasing challenge of drilling in Ultra Deepwater environments which form the cornerstone of future field developments. The deepwater environments are characterised by complex temperature profiles and geological features such as High Pressure-High Temperature (HP-HT) with very narrow pore pressure-fracture pressure window; Shallow unconsolidated reservoirs with very high overburden; Combination of ‘'flexible" lithologies. In these environments the use of overbalanced drilling techniques becomes difficult as the tolerance between formation pressure, wellbore pressure and the pressure at which the formation will fracture becomes very small. This can lead to severe drilling problems with attendant increase in drilling costs to possible loss of well control itself. These deepwater environments can benefit from Managed Pressure Drilling (MPD) when effectively combined with casing drilling technique but its uptake has been rather slow.
For the industry to develop a managed pressure drilling capability that will allow today's generation of complex wells to be drilled safely with casing, it is necessary to develop models that will accurately simulate the MPD process and to embed these models within an easy to use, intuitive well design package for pre-planning and as a real time tool to monitor, diagnose and optimise downhole operations and provide forward simulations based on rig and downhole data.
This paper presents the unique algorithms developed to simulate the MPD process and to analyse the effects of soft issues on the wellbore flow and pressure regimes and impact on torque/drag.
The algorithms developed have been validated with live well data including pump rates, fluid properties and especially PWD and pump pressure data. The predictions and actual data have been found to be in very close agreement.
The results of algorithm validation are presented to illustrate how the simulator can be utilised for real time design as well as process optimisation especially for casing drilling versus standard drillstring scenario.. Highlights of the effects of the complex relationships between eccentricity, rotation and fluid rheology at bottom hole and riser conditions are also presented to illustrate the drilling process optimisation. The paper is concluded with guidelines on MPD operating windows for different scenarios and a brief description of the system architecture of the MPD Simulator – The MPDEEP.
Anti-inflammatory effect of chitosan oligosaccharides in RAW 264.7 cells
Authors: Yang Eun-Jin , Kim Jong-Gwan , Kim Ji-Young , Kim Seong , Lee Nam , Hyun Chang-Gu 
Published: December 2009

AbstractWe examined the effects of chitosan oligosaccharides (COSs) with different molecular weights (COS-A, 10 kDa < MW < 20 kDa; COS-C, 1 kDa < MW < 3 kDa) on the lipopolysaccharide (LPS)-induced production of prostaglandin E2 and nitric oxide and on the expression of cyclooxygenase-2 and inducible nitric oxide synthase in RAW264.7 macrophages. COS-A (0.4%) and COS-C (0.2%) significantly inhibited PGE2 production in LPS-stimulated macrophages without cytotoxicity. The effect of COS-A and COS-C on COX-2 expression in activated macrophages was also investigated by immunoblotting. The inhibition of PGE2 by COS-A and COS-C can be attributed to the blocking of COX-2 protein expression. COS-A (0.4%) and COS-C (0.2%) also markedly inhibited the LPS-induced NO production of RAW 264.7 cells by 50.2% and 44.1%, respectively. The inhibition of NO by COSs was consistent with decreases in inducible nitric oxide synthase (iNOS) protein expression. To test the inhibitory effects of COS-A and COS-C on other cytokines, we also performed ELISA assays for IL-1β in LPS-stimulated RAW 264.7 macrophage cells, but only a dose-dependent decrease in the IL-1β production exerted by COS-A was observed. In order to test for irritation and the potential sensitization of COS-A and COS-C for use as cosmetic materials, human skin primary irritation tests were performed on 32 volunteers; no adverse reactions of COSs usage were observed. Based on these results, we suggest that COS-A and COS-C be considered possible anti-inflammatory candidates for topical application.