bluuebunny/crossref_metadata_2025 huggingface dataset:
H2S Scavengers Injection: A Novel Evaluation Protocol To Enhance The Integrity Of Production Lines
Authors: Mendez Conchita , Magalhaes Alvaro A. Oliveira , Altoe Pedro , Acosta Eduardo
Published: July 2009

The phenomenon of reservoir souring occurs when the concentration of hydrogen sulfide (H2S) increases in the produced fluids. The origin of H2S has generally been linked with secondary recovery operations. One common secondary recovery operation involves the injection of water, often seawater. Many oil operators have associated seawater breakthrough with subsequent souring. H2S can also have geological origin (e.g. thermal decomposition of organic sulfur compounds which are present in some crude oils).

The corrosiveness of co-produced water from the oil reservoir will consequently change with reservoir souring. Though carbon dioxide can cause very severe corrosion (i.e., general and pitting) of steels, H2S corrosion is more localized, and can cause cracking. Hence, increasing H2S will not necessarily cause a linear increase in general corrosion rate, but rather induce sudden failures in susceptible materials.

One alternative to mitigate the effects of H2S in oil and gas production facilities is the injection of H2S scavenger chemicals at suitable points in the system. Liquid scavengers react with H2S to form stable water- or oil-soluble reaction products.

The effects and performance of H2S Scavengers at various operational parameters (i.e., type of crude, water cut, temperature, contact time, and flow pattern) are not completely understood. A laboratory testing protocol and experimental equipment was designed and constructed in order to:evaluate the performance of H2S scavengers under simulated multiphase flow field conditions, andfacilitate the selection of commercial products to be injected into oil lines through a gas-lift system and/or through umbilical lines.

This work presents field and laboratory data as well as a description of the basis of computational modeling developed for the control of H2S in off-shore production fluids through the injection of liquid H2S scavengers through gas lift or umbilical line. The ultimate goal of this chemical treatment is to control the corrosion of carbon steel risers for a reliable operation during the lifetime of the producing wells by controlling the levels of H2S.

The major achievement of this work is the development of a testing and simulation approach to select the best chemical treatment and optimal doses minimizing the cost and uncertainties associated to field trials particularly when production conditions change.
SS:Geohazard Risk Assessment-Pipeline integrity in geohazard prone seabed terrain - what is the real risk?
Authors: Nicholls James
Published: July 2009

Geohazard features can now be mapped in great detail to all required water depth as a routine and mature task for the design and installation of submarine pipelines. The perceived risk associated with some of these highly characteristic morphological and geotechnical phenomena remains however a combination of quantitative modelling and engineering judgement.

This note references examples of several deepwater long distance pipeline projects in which geohazard has played a dominant factor in the assessment of risk to the pipeline, and revisits the application of engineering geohazard assessment to pipeline routeing and design. Geohazard in this context is limited to geological process at or near seabed that could result in catastrophic damage and loss of containment.

Introduction

Project's requiring the design of a pipeline system that traverse's coast margin shelf, slope and deepwater basin, will encounter a range of ‘normally’ expected and generally well understood geological terrain, each of which will include characteristic process and features at the seabed presenting potential risk to pipeline integrity. Pipeline engineering in deepwater therefore requires an early and authoritative appreciation of the regional setting for route selection, in support of key decisions regarding project concept, feasibility and investment

The observations and opinions discussed below are from the author's experiences both in the engineering supervision of geohazard specialists and as Project Management Team advisor on engineering geoscience and survey aspects for deepwater pipeline design.

Base Data

The overall bathymorphological configuration of coastal shelf, slope and abyssal plain for long distance pipelines is initially established from public domain bathymetry, generally satellite derived data (approaching 1 km resolution) and maritime navigation charts. Mature area development projects locally benefit from high quality exploration derived bathymetry data as a starting point (normally better than 100m resolution). In certain areas of high academic and industry funded research interest, we may be fortunate to access reconnaissance survey grade bathymetry data (typically 30 m resolution) including geophysical data and geological cores with regional interpretation.

During the subsequent Engineering Design phases, the resolution and fidelity of the seabed imagery and quantitative description improves to a point at which confidence in the final assessment of risk to the physical and economic security of the pipeline can be validated. However, it remains the careful and considered planning of initial route geometry and provision for alternatives at the project feasibility level which governs overall efficiency of engineering effort and the most appropriate final design alignment.
SS - Sakhalin-1: Regulatory and Environmental Management
Authors: Tyler David C. , Egging D.E. , Fedak M.E. , O'Reilly J.E. , Gauptman E. , Reep B.E. , Romanova M. , Scott M.J.
Published: July 2009

This paper reviews the environmental and regulatory performance of ExxonMobil Development Company (EMDC) and its contractors during Phase-1 development of the Sakhalin-1 Project Chayvo Field offshore Sakhalin Island, Russia, from 2002 through 2007. The Sakhalin-1 Project is being developed under a Production Sharing Agreement (PSA) with ExxonMobil's local affiliate, Exxon Neftegas Limited (ENL), serving as the operator for an international consortium of Russian, Japanese and Indian partners. 1

The Phase-1 development of Chayvo field is the first year-round offshore project to be completed in Russia. First oil was in October 2005 and the project reached full production by February 2007. To ensure good relationships and support from local, regional and federal government authorities, ENL implemented its global best practices for environmental performance and regulatory compliance. As measures of its success, ENL was awarded Foreign Project of the Year by the Russian publication, RusEnergy in 2006 and received the Excellence in Project Integration Award at the 2008 International Petroleum Technology Conference.

This paper demonstrates the need for early, comprehensive planning for environmental performance and regulatory compliance, including project approvals and permitting. It describes Russia's dynamic and complex regulatory framework and underscores the value of local expertise and professional relationships with Russian authorities. This paper also offers lessons learned from ENL's efforts to monitor Western gray whales and Steller's sea eagles, its oil spill prevention planning, archaeology, public consultation and other programs. The information and related lessons learned may be useful for future oil and gas developments, and could help benchmark similar projects or identify issues that other operators might face.

Introduction

The Sakhalin-1 oil and gas development, located on the northeast shelf of Sakhalin Island, includes the Chayvo, Odoptu and Arkutun-Dagi fields. Together they contain an estimated 2.3 billion barrels (307 million tons) of oil and 17.1 trillion cubic feet (485 billion cubic meters) of natural gas. Although hydrocarbons were discovered offshore Sakhalin in the 1970s, the technology to produce them was not available. The current phase of exploration and development began when the production sharing agreement became effective in 1996.

Exxon Neftegas Limited (30 percent) operates the Sakhalin-1 Project. The consortium includes two Russian companies, Sakhalinmorneftegas-Shelf (11.5 percent) and RN-Astra (8.5 percent), the Japanese company, SakhalinOil and Gas Development Co., Ltd. (30 percent) and India's ONGC Videsh Ltd. (20 percent). Both Russian partners are affiliates of Rosneft, the Russian state-owned oil company.
SS: Cryogenic Pipeline-Risk Analysis of LNG Pipe in Pipe Options
Authors: Spitzenberger Cynthia M.
Published: July 2009

A liquefied natural gas (LNG) liquefaction terminal used a comparative risk assessment to evaluate four different pipe-inpipe options for the loading line design to an offshore jetty system. The safety risk posed by the installation was evaluated with a quantitative risk assessment (QRA) procedure. A separate qualitative assessment was performed to evaluate the security risks associated with the project. Evaluation of the pipe-in-pipe and pipe-in-pipe-in-pipe technologies required additional frequency analysis to address the extra protection layers provided by the multi-pipe designs. The risk assessment process for the novel designs provided a more detailed basis for selection between the alternatives.

Introduction

Quantitative risk assessment (QRA) is a systematic analysis of the risks posed from hazardous activities or situations. The quantified or calculated results can be used in support of decision making. A liquefied natural gas (LNG) liquefaction terminal used a comparative risk assessment to evaluate four different pipe-in-pipe options for the loading line design to an offshore jetty system. The safety risk posed by the installation was evaluated with the traditional quantitative risk assessment procedure. A qualitative assessment was performed to evaluate the security and economic risks associated with the project.

Methodology

The approach used in the study was that of a classical risk assessment (CCPS 1999); a systematic approach to the analysis of what can go wrong in complex industrial systems. The normal conditions of operation of the system are defined and then the following questions asked:What accidental events can occur in the system?How frequently would each event occur?What are the consequences of each event?What are the total risks (frequencies multiplied by consequences) of the system?What is the significance of the calculated risk levels?

These questions correspond to the basic components of risk assessment discussed in Figure 1. Once a system has been analyzed, if the risks are assessed to be too high according to the desired criterion, the system would be modified in order to reduce the risks to a tolerable level, and the risk levels then recalculated. The process may therefore be viewed as iterative, where the design and/or operation of the system may be changed until it complies with the needs of society.
Managing Geohazards on Offshore Oil and Gas Projects
Authors: Carmichael Robert , Blackmore Malcolm Stuart , Nunan Frank
Published: July 2009

When one considers the areas throughout the world where seabed geohazards exist, their significant to the offshore oil and gas industry becomes apparent. The potential impact of geohazards on offshore development projects can range from increased intervention works which impact project schedule and costs, to scenarios where the overall integrity of the facility over its design life is at risk. The technical and commercial challenges posed by geohazards are more acute on projects with marginal economics, on fast track schedule projects, and where turnkey installation contracts are used. The earlier in a project cycle that geohazards are assessed, the more can be done to mitigate their effect on the project and this can be achieved at appraisal or concept selection phases by performing a desktop study which can use exploration seismic data as an invaluable source of information regarding the development area. It is recommended that geohazard specialist be engaged during such a desktop study and retained through the various design stages of the design to ensure continuity in the work. This can prove difficult to manage contractually, however it is still considered to be the optimal technical solution. Risk assessment based approaches are generally used to manage the risks associated with geohazards. The geohazard risk assessment process is iterative and requires the detailed geophysical and geotechnical survey data, hence the implications of any serious consequences arising from the geohazard risk assessment may only be know at an advanced stage of a project.

Introduction

In areas prone to seabed geohazards, these can pose serious risks to offshore oil and gas production facilities, personnel and the environment. This paper provides an overview of seabed geohazards and their potential impact on offshore oil and gas projects. It also critiques how geohazards are typically managed during the implementation of such projects through the various stages from concept selection through design, and construction. Specific areas addressed are planning, data gathering, mangagment of engineering and the effects of geohazards on project schedules. Recommendations to improve the management of geohazards are also discussed.
SS: Agbami Field Development: Agbami Project: People and Partnerships Delivering a World Scale Field Development
Authors: Bloomer Craig
Published: July 2009

The Agbami Project successfully commenced production in July 2008, ten years after the discovery of this world-class reservoir. Agbami represents one of Chevron Corporation's largest capital investments of the decade and the project achieved many outstanding results, overcoming various challenges along the way. This paper provides an overview of the project and discusses the key project objectives, strategies employed and some of the lessons learned, such as:establishing a world-wide incident and injury free culturebuilding the largest FPSO in the world and an extensive subsea production systemapplication of intelligent well completions for reservoir managementsetting new standards in Nigerian Contentachieving schedule objectives and production reliability in a challenging cost environment

Agbami is a unitized deepwater oil field offshore Nigeria. Star Deep Water Petroleum Limited, an affiliate of Chevron Corporation, is the operator of the Agbami Unit. It took partnership with the concessionaires, Nigerian National Petroleum Corporation, Famfa Oil Limited, and the other funding participants: Statoil Nigeria Limited, Petroleo Brasileiro Nigeria Limited, and Texaco Nigeria Outer Shelf Inc. (an affiliate of Chevron Corporation), as well as countless contractors and suppliers across the globe to achieve this remarkable outcome. Earning their support required a strong commitment to finding solutions, focus on interface management, and responsiveness to each stakeholder's interests.

Introduction

The Agbami field started production on 29 July 2008, a result of the efforts of a worldwide team of tens of thousands of people. In the ten years since the field's discovery, the project overcame a wide range of challenges to safely set new standards in Nigerian Content and expand technology boundaries. This paper, and related papers of the OTC conference, provides an overview of the project and highlights some of its accomplishments.

Discovery and Early Partnerships

The Agbami discovery in 1998 hailed as the largest oil field discovery of the year with estimated recoverable reserves exceeding 900 MM BBLs. The largest deepwater field in Nigeria extends across two blocks, OML 126 and 127, with Famfa Oil Limited and Nigerian National Petroleum Corporation as concessionaires. Star Deep Water Petroleum Limited (an affiliate of Chevron Corporation) is the Unit Operator, and Statoil Nigeria Limited, Petroleo Brasileiro Nigeria Limited and Texaco Nigeria Outer Shelf Inc. (an affiliate of Chevron Corporation) are funding partners. As an early signpost to the level of partnership needed to develop Agbami, after six years of appraisal and project planning, the parties established the first deepwater Unit Agreement in Nigeria in 2004. From that point onward, the Agbami project was on its way to production.
Low-Frequency Drill Bit Seismic While Drilling
Authors: Radtke Robert Paul , Fontenot John , Glowka David , Stokes Robert
Published: July 2009

A breakthrough has been discovered for controlling seismic sources to generate selectable low frequencies applicable to many seismic applications. All possible borehole pulsed sources, including hydraulically driven devices, explosives, and etc., by their very nature produce high frequencies. This is counter to the need for long transmission through rock. Specifically, we are reporting the application of an otherwise high frequency sparker source on the drill string for Drill Bit Seismic While Drilling (SWD). The low frequency source provides real-time imaging in deep (15,000 feet+) high-temperature (150°C) high-pressure (HTHP) wells ahead of the bit for accurate pore pressure determinations and geosteering, reservoir model verification, and near wellbore diagnostics. Furthermore, to have additional energy available at the drill bit can result in increased rates of penetration.

Introduction

It has been said, " The time is coming when we will not drill without looking ahead of the bit anymore than we would drive at night without headlights - occasionally shining a lamp to see what we hit.?? An alternative seismic source for the roller bit as it was being replaced by the PDC bit is something oil and service companies have sought since the early 1990's.

A breakthrough has been discovered for controlling seismic sources to generate selectable low frequencies (< 40 Hz) applicable to many seismic applications. All possible borehole pulsed sources, including hydraulically driven devices, sparkers, explosives, etc., by their very nature produce high frequencies. This is counter to the need for long distance transmission through rock. Specifically, we have demonstrated the application of an otherwise high frequency sparker source which can be encorporated into a drill bit for Drill Bit Seismic While Drilling (SWD). The low frequency source, capable of creating selectable mid-band frequencies of 1 to 20 Hz, provides a source to perform real-time imaging in deep (15,000 feet+), high-temperature (150 degrees C), high-pressure (HTHP) wells for (a) geosteering, (b) accurate seismic hole depth, (c) accurate pore pressure determinations ahead of the bit, (d) near wellbore diagnostics with a downhole receiver and wired drill pipe, and (e) reservoir model verification. Furthermore, to have additional energy available at the drill bit for rock desintergation can result in increased rates of penetration.
SS: Agbami Field Development: Subsea Installation Contract, Overcoming the Challenges
Authors: Sanders David , Chauvin Frederic
Published: July 2009

The subsea installation contract (SIC) for Agbami was awarded by Star Deep Water Petroleum Ltd (an affiliate of Chevron Corporation) to Technip in May 2005. The scope of work included the design, fabrication and installation of nearly 100 km of flexible risers, flowlines and jumpers, and 45 km of static and dynamic umbilicals. It also included the installation of various Star Deep Water provided items including 12 piles and manifolds, 82 electrical flying leads and 51 hydraulic flying leads.

The project is in approximately 1,550m of water and represents one of the world's largest subsea installation contracts awarded.

The key logistical challenges for this very large project were to ensure the safe and timely delivery of the flexible and umbilical products, and the real time coordination of logistics associated with their transportation from Europe to Nigeria using a fleet of five heavy lift transport vessels and installation in the field. Installation had to be coordinated with the FPSO and other subsea contractors working in the field, as well as simultaneous field operations with drilling vessels throughout the installation phase. Additionally, working offshore Nigeria presented its own set of challenges including security and other operational constraints.

Of the technical challenges, the risers are the longest single section of flexibles to have been manufactured and installed to date. Production risers and flowlines may need to transport a mildly sour well fluid in the future, hence control of the permeation of hydrogen sulphide into the annulus was a significant issue that required an innovative design.

This paper will present an overview of the subsea systems employed for the Agbami field and outlines some of the particular challenges that the project team had to respond to, including:Flow assurance requirements and the consequent thermal performance required from the systemThe implications of potential sour produced fluid on the design of the flexibles.Scheduling of the installation activities around available windows including the early installation of piles, manifolds and static umbilicalsSuccessful offshore precommissioning of the production lines and associated control systems which were required for First Oil while continuing to progress the remainder of the installation programmeLogistics associated with transport of a very large quantity of products from Europe and delivery to Nigeria, along with the need for management of in-country logistical and safety support servicesThe constraints imposed by the available crane capacities and how they were resolved
SS: Canadian: Atlantic Development; Technological Advances to Assess, Manage and Reduce Ice Risk in Northern Developments
Authors: Randell Charles , Freeman Ralph , Power Desmond , Stuckey Paul
Published: July 2009

As the number of oil and gas players in Arctic and sub-Arctic regions increases, so do the suite of technology-based capabilities for cold region operations. Advances are being made in remote sensing, ice management, and ice engineering. R&D targeted to increase our understanding of the ice environment and ice mechanics is reducing uncertainties relating to ice loads. C-CORE and partners have been developing and providing technical solutions to most recent oil and gas initiatives facing the challenge of sustainable development in ice covered regions. Using this work as background, this presentation will highlight recent and imminent technological advances providing near-term improvement in the economics of cold ocean hydrocarbon production.

Background

Offshore oil and gas exploration began on the Grand Banks of Newfoundland in 1966 with the first major discovery, Hibernia, occurring in 1979. The discovery of Hibernia was the result of a joint exploration venture by Chevron and Mobil. Other major oil and gas discoveries on the Grand Banks followed with Hebron in 1981 and the White Rose and Terra Nova Fields in 1984. First oil was produced from Hibernia in 1997, Terra Nova in 2002, White Rose, 2005 with Hebron expected to be 2017-18. A number of R&D initiatives were undertaken in order to develop these resources safely and in the most cost effective manner possible. In the early 1980s comprehensive data collection programs were initiated by Mobil to develop a design basis for the Hibernia development (Dobrocky, 1984). Aerial surveys were conducted for above water iceberg characterization (size and mass) as well as iceberg profiling for below water geometry for mass. In 1996, Grappling Island iceberg impact experiments were carried out; the first ever iceberg impact experiments (Ralph et al, 2004). Research and development into ice mechanics and design load algorithms pioneered by Dr. Jordaan at the Ocean Engineering Research Center at Memorial University Canadian Offshore Design for Ice Environments (CODIE) project have made a tremendous impact in design for these harsh environments (CODIE I, 1997 and CODIE II, 2003). More recently, an improved understanding of ice mechanics and failure processes have led to an improved basis for global design loads based on a reduced iceberg pressure on large contact areas from 6.0 MPa used in the Hibernia design basis to a still conservative 1.5 MPa presently used for Hebron studies.

From 1999 to 2005, C-CORE led a comprehensive Ice Management R&D JIP addressing technology challenges relating to detection and towing. Research and development continues with improvements and optimized methods for ice management (detection, forecasting, threat analysis, decision-making and iceberg towing), the modeling of ice management effectiveness for design, and improved methods for iceberg collision and design load analyses.
SS: Canadian: Atlantic Development: The Value of Wellness
Authors: Wahl Mike Jonathan , Oneil Mike , Cooper T.
Published: July 2009

Description of the Proposed Paper:

The value of wellness paper is a comprehensive research review that proposes a conceptual model of the costs associated with high and low risk employees on an annual and career model. This model accurately addresses the variables specific to the oil and gas industry including the internal and external factors which must be addressed by the organization prior to engaging in wellness activities. This paper accurately portrays the specific costs by division as well as highlights the effect of wellness on safety as it relates to health as well as regulatory burden and license to operate.

Application:

This conceptual model provides the audience with the accurate costs, factors and concerns associated with wellness initiatives in remote environments. Several factors such as senior managements role, medical costs, replacement workers and re-training are relayed to the audience encompassing the full scope of wellness risk as it exists in the offshore.

Results, Observations, and Conclusions:

The value of wellness paper quantifies that a high risk employee can cost a company $125,000 per year if encompassing all high risk factors and up to 2.65 million dollars over the course of a career. This paper concludes that by adopting a wellness culture and controlling for wellness risk the organization can avoid serious costs and gain intangible advantages in regulatory burden, license to operate and brand equity and company loyalty.

Significance of Subject Matter:

Wellness may be a substantial contributer to both HSE and value to an organization. Companies controlling for wellness risk with a comprehensive wellness program will control costs, operational issues such as safety and license to operate as well as retain and maintain employees in a competitive aging job market.

Introduction

Organizations frequently ask wellness professionals specific questions around the cost of wellness. How much does it cost to run a ‘best practice’ wellness program, how much should our cost be relative to our risk in an approach to employee's wellness and are our current wellness arrangements cost-effective? The reason for focusing on cost is that financial directors, board members and human resources directors have all identified cost minimisation as a critical element in ensuring an efficient and effective approach to an employee's wellness as part of a wider human resources and operational strategy. The following document demonstrates that examining the cost of wellness is just one part of the equation. Organizations also have to examine the value a wellness program provides.
SS: Unlocking the Unconventional Oil and Gas Reservoirs: Potential for Oil Shale Development in the United States
Authors: Biglarbigi Khosrow , Killen James Curtis , Mohan Hitesh , Carolus Marshall John
Published: July 2009

The development of domestic oil shale resources has regained significant attention in the past few years. Several factors have contributed to this, including high oil prices, emerging recovery technologies, increasing world demand for liquid hydrocarbons, and the continued decline in U.S. conventional oil production. In recent years, several initiatives have been taken by the Federal Government and the private sector to encourage the development of a domestic oil shale industry.

The United States has vast deposits of oil shale - Nearly 2.0 trillion barrels across the eastern and western states. The development of this massive resource, however, is constrained, however, by a number of key factors including, but to limited to;resource access,technology,economics,environmental and regulatory issues, andinfrastructure.

A comprehensive analysis has been completed to review emerging oil shale technologies from 23 companies and identify options to accelerate the development of this resource. The analysis is based on a representative sample (about 70 Billion Barrels) of Western Oil shale resource divided among multiple development " tracts??. The presentation will present a summary of the technologies; including but not limited to emerging in-situ processes as well as traditional mining with surface retorting technology. Each development " tract?? was screened for the potential application of representative recovery technologies. A detailed economic evaluation was conducted for each " tract?? and the selected technology with consideration for development under alternative economics, environmental, technology, and socio-economic options. The analysis indicated that with a concerted effort from industry, local, state, and Federal governments, the oil shale production potential could reach 2.5 million barrels per day (MMBbl/d) with substantial benefits to the local and national economy.

Introduction

Oil shale is carbonate rock, generally marlstone that is very rich in organic sedimentary material called " kerogen.?? Oil shales are " younger?? in geologic age than crude oil-bearing formations; natural forces of pressure and temperature have not yet converted the sediments to crude oil. Kerogen can be converted to superior quality jet fuel, #2 diesel, naphtha, and other high value by-products. The kerogen content of " oil shale?? ore can range from 10 to 60 or more gallons of oil per ton2.

Worldwide, there are nearly 10 trillion barrels of shale oil resource. These resources are located in North America, South American, Europe, Middle East, North Africa (MENA), Asia, and Australia (Figure 1). Table 1 shows the resource for the top ten countries. Nearly 60% of the total resource is located in the United States with significant deposits in the western and eastern states.
Flow Assurance Challenge for Offshore Deep Water in Republic of Congo
Authors: Monahan Peter
Published: July 2009

Until now, offshore oil and gas production in the Republic of Congo has been restricted to the area covered by shallow water technology, up to water depths of around 200m. The Moho Bilondo development is the first deepwater development in these offshore Congolese waters and this paper presents the flow assurance issues that have been addressed during the design, construction, installation and start-up of this field.

The development comprises of production from the two reserves of Mobim and Bilondo. To meet the challenging project schedule the flow assurance aspects of the process design had to play their part and had to be both functional and robust. This paper presents the flow assurance issues that have been addressed during the development of the project.

The challenges for flow assurance fall into three categories. Firstly, the hydrodynamic issues had to be addressed. Bilondo oil is relatively heavy and requires gas lift injected downhole to achieve the desired recovery of reserves. At the same time, the down-sloping nature of the sea bed terrain from the Bilondo manifold can present the typical problems of induced slug flow regime. Management of the gas lift strategy was therefore key to the operating philosophy.

The thermal insulation performance to provide the required cooldown time for preservation had to be achieved for the entire subsea production system, so as to avoid the formation of hydrates during prolonged shutdowns. Making matters worse is the downhole supply of cold lift gas via the Xmas tree, which has a cooling effect on the production fluid in the tubing. An additional risk identified here was that of wax formation on the inner tubing wall. Significant finite element studies were performed on the Xmas tree wet insulation to achieve the desired thermal performance.

Thirdly, the risk to production by the formation of naphthenate soap deposits was also assessed. Steps were taken in the design of the topsides process and of the chemical injection strategy, dosing rates and injection points both subsea and on the topsides, to manage these risks.
Moho Bilondo Compact Development: Layout and Planning Management
Authors: Carrier Pascal
Published: July 2009

Moho Bilondo - Compact development: layout and planning management

During the concept studies of Moho Bilondo, it was decided to develop two reservoirs: BILONDO and the new reservoir MOBIM, discovered in September 2004. This development is considered as a compact field, due to small distance between the two reservoirs: only 4.6Km.

A flexible pipeline concept for flow lines and risers was selected in order to develop this field, which was capable of accommodating the flow assurance, and insulation (cool down time) requirements of the fields. In addition, this concept reduced the development costs.

The field layout is comprises two developments areas MOHO and BILONDO with a FPU (Floating Production Unit) moored in the middle of these two reservoirs. Each field is linked to the FPU by:–2 flexible production 8'' (flow lines + risers) in loop–1 GLU (Gas lift Umbilical)–1 E/H Umbilical

Water injection on BILONDO field is provided via a rigid pipe 8'' coming from NKF2 platform on NKOSSA field, and the water injection for MOBIM is perform by a flexible network from FPU desulfatation unit (flexible riser and flowline 8'' from FPU to ITA, and flexible flowline 6'' from the ITA to remote WI well).
When Failure is not an Option: Managing Megaprojects in the Current Environment
Authors: Westney Richard E. , Fort Joel , Lucas James , Messier Luc , Vardeman R.  Don D. , Renfro Kevin
Published: July 2009

Introduction

This manuscript is intended to set the stage for the OTC General Session Panel discussion entitled " When Failure is not an Option: Managing Megaprojects in the Current Environment??, scheduled for Thursday, May 7, 2009. Members of this panel session are as follows:Richard Westney, Chairman, Westney Consulting Group (Panel Moderator)Joel Fort, General Manager, Yemen LNGJames Lucas, President & CEO, Luman InternationalLuc J. Messier, Senior Vice President - Project Development and Procurement, ConocoPhillipsDon Vardeman, Vice President -Worldwide Projects, Anadarko Petroleum Corporation

Megaprojects can be defined as projects that are so large that the conventional body of project and risk management knowledge is insufficient to ensure success. Given that significant overruns and delays on megaprojects are almost the norm, it appears that no one really has all the answers to meeting the special challenges of these huge projects.

Failure is not an option for most megaprojects. The level of investment, the magnitude of the cashflows involved, and the organizational commitment required are such that the impact of bad outcomes can be devastating to the operator, partners and host countries involved.

Megaprojects create challenges that, although now fairly typical, have not typically been addressed in the past. Given the relatively small number of past megaprojects, and their long duration, many executives and practitioners have limited or no experience with them - and the experience of those that do is often not the sort that one would wish to repeat. New approaches are needed, many have been tried, and a new body of knowledge is emerging for these very large projects.

The panel is made up of people who are very experienced in megaprojects, representing the executive and project manager points of view, the owner and contractor points of view, as well as the independent perspective of consultants. Rather than focus on success stories, the panel will focus on the most difficult / challenging / intractable aspects of megaprojects and, with extensive audience participation, discuss what has worked, what has not, and what is needed going forward in the current energy and economic environment. Participants will take away an improved understanding that will assist in their planning and decision-making.
Panel: Collaboration Between Companies, Cosumers, and the Government for Future Energy Needs
Authors: Holt David , Khurana Sandeep
Published: July 2009

Preface

This manuscript is intended to set the stage for a panel discussion, " Meeting the Energy Challenge: Improving Communication among Consumers, Academia, NGOs, Oil Companies, and Government??, scheduled for Monday, May 4th, 2009. The panel will be composed of representative from each one of these entities, namely Consumers, Academia, NGOs, Oil Companies and Government to discuss how to meet the energy challenge. The panelists are as follows:Marvin Odum, President of Shell Oil Company and Executive Vice President for the Americas for Shell Exploration & Production (Confirmed)The Honorable Lisa Murkowski, U.S. Senate (invited)The Honorable Sheila Jackson Lee, U.S. House of Representatives (invited)John Holdren, Presidential Science Advisor (invited)Governor John Engler, President of National Association of Manufacturers (invited)Governor Bill Graves, President of American Trucking Associations (invited)Dr. Henry Lee, Harvard Kennedy School (invited)Phil Sharp, President, Resources for the Future (invited)

And the moderators:David Holt, Executive Director, Consumer Energy AllianceSandeep Khurana, Advisor, Devon Energy Corporation

Theme

The worldwide quest to define future energy needs has brought the issue of partnership among consumers, academia, NGOs, oil companies and the government to the forefront. World energy supply is predicted to rely heavily on fossil fuel resources for the foreseeable future. However, short-term vision has sometimes discouraged, even shut-off, expanded exploration by oil companies, further weakening our supply lines. Some oil companies are investing in alternative sources, but these resources can merely keep pace with demand. Meanwhile, consumers are struggling with price fluctuations and political leaders are overwhelmed with rhetoric and the constant struggle to develop a comprehensive, balanced national energy policy.
Ronco em Crianças
Authors: Prado Lucila Bizari Fernandes do , Cardeal José Osmar , Cardeal Marina , Prado Gilmar Fernandes do
Published: July 2009

0 ronco é produzido pela vibração do palato mole e dos pilares das amígdalas. Ele é considerado um sintoma cardinal dos distúrbios respiratórios obstrutivos do sono - um marcador de apnéia obstrutiva do sono. E mais freqüente no adulto obeso do sexo masculino. No entanto, as crianças também podem apresentar ronco e apnéias obstrutivas. Diferentemente dos adultos, que possuem ronco associado com sonolência excessiva diurna, na criança os sintomas diurnos estão relacionados com problemas de comportamento e distúrbios de escolaridade. Neste artigo, os autores apresentam uma revisão sobre os aspectos históricos, fisiopatologicos, epidemiológicos, etiológicos e clínicos do ronco em crianças.
Utilização do SF-36 em ensaios clínicos envolvendo pacientes fibromiálgicos
Authors: Vitorino Débora Fernandes de Melo , Martins Fábio Luiz Mendonça , Souza Alessandra de Castro , Prado Gilmar Fernandes do
Published: July 2009

Objetivo: Definir um acréscimo mínimo de pontuação para cada domínio do questionário de qualidade de vida SF-36 aplicado a pacientes com fibromialgia, que possa expressar uma melhora clinicamente significativa, almejada para esses pacientes. Método: O questionário SF-36 foi analisado, em cada um dos seus domínios, por quatro fisioterapeutas. Cada profissional baseando-se em sua experiência com pacientes fibromiálgicos estipulou um índice de variação mínimo para cada domínio, considerando sempre o que exprimia cada questão. Em todos os domínios os profissionais citados foram requeridos a supor que variação de pontuação esperariam após um tratamento fisioterápico. Foram calculados a média, o desvio padrão e a concordância entre os fisioterapeutase, em seguida, foi estipulado qual o acréscimo de pontuação seria necessário para que o paciente fosse considerado melhor clinicamente naquele domínio. Resultados: Foram determinadas as seguintes pontuações mínimas de acréscimo em cada domínio para que o paciente fosse considerado clinicamente melhor: Capacidade Funcional 15 pontos, Aspecto Físico 25 pontos, Dor 10 pontos, Estado Geral de Saúde 15 pontos, Vitalidade 15 pontos, Aspecto Social 12,5 pontos, Aspecto Emocional 33,3 pontos e Saúde Mental 12 pontos. Conclusão: A menor variação positiva esperada pelos fisioterapeutas para que considerassem melhora foi 10 pontos (dor) e a maior 33,3 pontos (aspecto emocional), compatível com as médias de variações observadas em estudos semelhantes.
Midazolan nasal no tratamento de crises convulsivas
Authors: Rizzutti Sueli , Prado Lucila Bizari Fernandes do , Prado Gilmar Fernandes do
Published: July 2009

Pacientes com crises agudas incluindo estado de mal epiléptico, podem apresentar dificuldades no tratamento que geralmente envolve um benzodiazepínico. As drogas mais amplamente utilizadas em pacientes com crises agudas incluem diazepam, lorazepam e midazolam. Nós revisamos a eficácia e a segurança das diversas formas de administração do midazolam. A administração intranasal e bucal do midazolam pode ser uma alternativa a administração retal e intravenosa do diazepam.
Síndrome das Pernas Inquietas
Authors: Masuko Alice Hatsue , Prado Lucila Bizari Fernandes do , Prado Gilmar Fernandes do
Published: July 2009

A síndrome das pernas inquietas é doença bastante prevalente e pouco reconhecida pelos agentes de saúde. A maior parte dos pacientes não estão recebendo atenção médica, ou mesmo recebendo terapêuticas que pioram ainda mais os já insuportáveis sintomas. Muito conhecimento vem sendo acumulado nos últimos anos sobre essa doença, e o tratamento tem-se diversificado mais. Os agonistas dopaminérgicos vêm assumindo importante papel no manejo terapêutico destes pacientes, mas ainda necessitamos de ensaios clínicos com desenhos mais realísticos, principalmente abordando qualidade de vida e efeito a longo prazo dos agentes terapêuticos
Paralisia cerebral Aspectos Fisioterapêuticos e Clínicos
Authors: Leite Jaqueline Maria Resende Silveira , Prado Gilmar Fernandes do
Published: July 2009

A paralisia cerebral congrega um grupo de afecções permanentes do sistema nervoso central sem caráter progressivo e de instalação no período neonatal. Há várias abordagens terapêuticas com possíveis benefícios ao paciente com paralisia cerebral, porém poucas embasadas em evidências científicas indiscutíveis. A abordagem fisioterapêutica teria a finalidade de preparar a criança para uma função, manter ou aprimorar as já existentes, atuando sempre de forma a adequar a espasticidade. Entretanto, o prognóstico da paralisia cerebral depende evidentemente do grau de dificuldade motora, da intensidade de retrações e deformidades esqueléticas e da disponibilidade e qualidade da reabilitação. Este artigo revisa aspectos clínicos da paralisia cerebral, discutindo a fisioterapia e as diversas abordagens terapêuticas utilizadas.
Os efeitos da acupuntura no tratamento da insônia:
Authors: Silva Filho Reginaldo Carvalho da , Prado Gilmar Fernandes do
Published: July 2009

Introdução. A insônia é uma queixa muito comum e a acupuntu-ra tem sido empregada em seu tratamento por milhares de anos, porém até o momento não dispomos de estudos científicos com evidências que comprovem sua eficácia. Objetivo. Identificar es-tudos clínicos de valor científico sobre os efeitos da acupuntura no tratamento da insônia. Método. Revisão sistemática com busca de artigos nas bases de dados: MEDLINE, Cochrane Library, Bio- Med Central, BMC Complementary and Alternative Medicine, SciELO, LILACS, ACUBRIEFS e Library of Shandong Unvier-sity of Traditional Chinese Medicine. Foram utilizadas as pala-vras chaves “ACUPUNTURA”, “AURICULAR” e “INSÔNIA”, em inglês, espanhol e francês. Foram incluídos ensaios clínicos, estudos ou séries de casos; com objetivo principal a avaliação do uso da acupuntura no tratamento da insônia; com desfecho a me-lhora, piora ou manutenção da insônia. Foram excluídos artigos sobre queixa diferente da insônia mesmo que relatasse alteração nesta queixa. Resultados. Foram encontrados 180 artigos, 31 pre-encheram os critérios de inclusão. Um total de 3574 pacientes fo-ram analisados, 1359 participaram de dos 11 estudos controlados. Os resultados nos grupos de acupuntura e controle, apareceram respectivamente em 412 (57,46%) e 141 (21,96%) para cura, 264 (36,82%) e 232 (36,14%) para melhora e 41 (5,72%) e 269 (41,90%) para falha. Conclusão. Os resultados encontrados suge-rem que a acupuntura pode ser uma intervenção eficaz para inso-nes, no entanto trabalhos com melhores e mais rigorosos métodos, como ensaios clínicos randomizados, controlados, simples-cego, e com amostras maiores devem ser realizados para determinar melhor a eficácia da acupuntura no tratamento da insônia.
Impacto da fisioterapia no tratamento da vertigem
Authors: Teixeira Lázaro Juliano , Prado Gilmar Fernandes do
Published: July 2009

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Editorial
Authors: Prado Gilmar Fernandes do , Carvalho Luciane Bizari Coin de , Machado Marco Antonio Cardoso
Published: July 2009

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Versatile, Benzimidazole/Amine‐Based Ambipolar Compounds for Electroluminescent Applications: Single‐Layer, Blue, Fluorescent OLEDs, Hosts for Single‐Layer, Phosphorescent OLEDs
Authors: Chen Chih‐Hsin , Huang Wei‐Sheng , Lai Mei‐Yi , Tsao Wen‐Cheng , Lin Jiann T. , Wu Ying‐Hsien , Ke Tung‐Huei , Chen Li‐Yin , Wu Chung‐Chih
Published: July 2009

A series of compounds containing arylamine and 1,2‐diphenyl‐1H‐benz[d]imidazole moieties are developed as ambipolar, blue‐emitting materials with tunable blue‐emitting wavelengths, tunable ambipolar carrier‐transport properties and tunable triplet energy gaps. These compounds possess several novel properties: (1) they emit in the blue region with high quantum yields; (2) they have high morphological stability and thermal stability; (3) they are capable of ambipolar carrier transport; (4) they possess tunable triplet energy gaps, suitable as hosts for yellow‐orange to green phosphors. The electron and hole mobilities of these compounds lie in the range of 0.68–144 × 10−6 and 0.34–147 × 10−6 cm2 V−1 s−1, respectively. High‐performance, single‐layer, blue‐emitting, fluorescent organic light‐emitting diodes (OLEDs) are achieved with these ambipolar materials. High‐performance, single‐layer, phosphorescent OLEDs with yellow‐orange to green emission are also been demonstrated using these ambipolar materials, which have different triplet energy gaps as the host for yellow‐orange‐emitting to green‐emitting iridium complexes. When these ambipolar, blue‐emitting materials are lightly doped with a yellow‐orange‐emitting iridium complex, white organic light‐emitting diodes (WOLEDs) can be achieved, as well by the use of the incomplete energy transfer between the host and the dopant.