bluuebunny/crossref_metadata_2025 huggingface dataset:
Effects of Antihypertensive Drug Treatment on the Risk of Dementia and Cognitive Impairment
Authors: Poon Ivy O.
Published: February 2008

Dementia is a common and serious health problem that affects 33 million persons globally. With the increase in life expectancy, the prevalence of dementia is expected to reach 81.1 million persons by 2040. Dementia impairs quality of life and is associated with profound disease burden, morbidity, and mortality in both patients and caregivers. Therefore, identifying measures to prevent dementia is a research priority. Midlife hypertension has increased the risk of dementia in large prospective cohort studies. Researchers have investigated the blood pressure‐lowering effects of antihypertensive drugs on the incidence of dementia. Although prospective cohort studies have shown that use of antihypertensive drugs was associated with a reduced rate of cognitive impairment and dementia, these studies were not placebo controlled. Four randomized, placebo‐controlled studies—the Systolic Hypertension in Europe (Syst‐Eur) study, Study on Cognition and Prognosis in the Elderly (SCOPE), Systolic Hypertension in the Elderly Program (SHEP), and Perindopril Protection Against Recurrent Stroke Study (PROGRESS)—investigated the effects of antihypertensive agents on the incidence of dementia. The Syst‐Eur study found that active treatment with nitrendipine, enalapril, and/or hydrochlorothiazide reduced the rate of dementia by 50% compared with placebo (p=0.05). The PROGRESS study showed that active treatment with perindopril and indapamide was associated with reduced cognitive decline compared with placebo (risk ratio 19%, p=0.01). In contrast, the SCOPE study (candesartan or hydrochlorothiazide vs placebo) and the SHEP trial (chlorthalidone, atenolol, or reserpine vs placebo) found no significant difference between the active treatment and placebo groups on the incidence of dementia. Some researchers have suggested that certain antihypertensive drug classes, such as angiotensin‐converting enzyme inhibitors, angiotensin II receptor blockers, diuretics, and calcium channel blockers, may offer benefit in reducing dementia risk in addition to their blood pressure‐lowering effect. Further prospective randomized studies comparing different antihypertensive classes are needed to provide more evidence regarding the effects of antihypertensive drugs on dementia risk and to determine whether certain antihypertensive classes provide greater benefits than others.
Clopidogrel‐Associated Bleeding and Related Complications in Patients Undergoing Coronary Artery Bypass Grafting
Authors: Pickard A. Simon , Becker Richard C. , Schumock Glen T. , Frye Carla B.
Published: February 2008

Objective. To determine if clopidogrel use before coronary artery bypass grafting (CABG) is associated with an increase in major bleeding, hemorrhage‐related complications, or transfusion requirements.

Methods. A structured literature search of English‐language articles was conducted by using MEDLINE, EMBASE, and the Cochrane Collaboration Database for the period of January 1, 1990‐April 30, 2007. Studies were included if they met the following criteria: randomized controlled trials, prospective observational trials, or retrospective trials; characteristics and outcomes of patients who were exposed to clopidogrel within 7 days before CABG were analyzed; at least 20 patients were enrolled; and reported outcomes were related to transfusion requirements, resource utilization, clinical events, or hemorrhage‐related reoperation rates. Patients were considered exposed to clopidogrel if they discontinued the drug within a specified time frame that was designated in each study. The rates of the outcomes were compared between those patients exposed and those not exposed to clopidogrel.

Results. Twenty‐three studies, with data on 3505 patients exposed to clopidogrel before CABG, met the selection criteria. Results suggested that clopidogrel exposure within 7 days before CABG increased the risk of major bleeding and related complications, such as reoperation and blood product transfusions. For other outcomes such as mortality, myocardial infarction, or stroke, the studies' designs lacked statistical power to detect significant differences. In five of the 23 studies, antifibrinolytic therapy with aprotinin was evaluated; in the other studies, aprotinin may have been administered, but it was not discussed in detail. In these studies, the clopidogrel‐exposed patients typically had significantly higher chest tube output volumes, reoperation rates due to bleeding, and greater transfusion requirements. Although aprotinin appeared to mitigate hemorrhagic risk, the drug has been temporarily suspended from the market due to safety concerns.

Conclusion. Clopidogrel exposure within 7 days before CABG is associated with an increase in major bleeding, hemorrhage‐related complications, and transfusion requirements, and leads to potentially greater consumption of health care resources. The overall risks and benefits for each patient should be considered before using the drug.
Implications of the change to Eurocodes for bridge design
Authors: Hendy C. R.
Published: February 2008

The use of Eurocodes on real projects in the UK highways sector is nearing reality. National Annexes for all the parts required for bridge design are nearing completion and should be ready by the end of 2007. The Highways Agency and British Standards Institution (BSI) committees are completing production of BSI Published Documents to give non-contradictory complementary information to help with the use of the Eurocodes and a variety of organisations are producing design guides. Despite the cultural and technical changes that the Eurocodes bring, pilot studies have shown that designers adapt remarkably quickly. There are also incentives to embrace the Eurocodes. The less prescriptive approach and more up-to-date rules provide the user with greater scope for innovation and economy. This paper identifies the various areas in steel and concrete design where there are technical differences between the new Eurocodes and BS 5400 and also where the new rules lead to the potential for greater structural economy.
Strengthening of Irwell Valley Bridge, UK
Authors: Smith D. A. , Hendy C. R.
Published: February 2008

The Irwell Valley Bridge in the UK comprises seven steel–concrete composite box girders with a simply supported span of 60·96 m at a skew of 23°. It carries the M60 motorway across the River Irwell adjacent to junction 16 and was constructed in 1970. Structural assessment highlighted deficiencies in the shear studs connecting the concrete deck slabs to the steel boxes, steel diaphragms and end cross-bracing. The first of these three deficiencies was addressed through a departure from standards, while the other two deficiencies required strengthening and modification. A means of jacking the boxes for future bearing replacement also needed to be provided. This paper identifies the various ways in which a cost-efficient and buildable design was produced for strengthening of the diaphragms and how detailing problems specific to strengthening a steel box with restricted access were overcome. Key to the project was the need to minimise disruption to the highway network and to work within tight programme constraints imposed by the hibernation and roosting requirements of bat colonies living within the bridge. The motorway was therefore kept open during jacking operations and multiple boxes were strengthened simultaneously. Due to the complexity of the construction sequence for the strengthening work, a virtual reality model of the bridge and all stages of strengthening was set up and distributed to all parties. The benefits of using this model to assist both design and work on site are discussed.
Technical Note: Double composite steel–concrete bridges
Authors: Collings D.
Published: February 2008

This technical note outlines the concept of double composite action. It summarises the potential advantages of a double composite steel–concrete structure over the more common steel–concrete composite construction, particularly for continuous structures. A comparative study of three bridge forms with and without double composite action is outlined and the reduction in steel tonnage for the double composite type of each form is estimated.
Bridge distress caused by approach embankment settlement
Authors: Jones C. A. , Stewart D. I. , Danilewicz C. J.
Published: February 2008

Surtees Bridge, which carries the A66(T) over the River Tees near Thornaby-on-Tees in the UK, has been showing signs of distress that predate its opening in 1981. Subsequent investigations have shown that the bridge distress is related to unexpectedly large settlement of the eastern approach embankment. Recent ground investigations prompted by a proposed widening of the river crossing have produced many new data on the alluvial deposits underlying the site, and explain why embankment settlement was so much larger than originally anticipated. Comparison of the geotechnical parameters obtained from the original and more recent ground investigations suggests that the original investigation significantly underestimated the thickness of an alluvial clay layer underlying the site, and that its coefficient of consolidation was overestimated. Settlement analyses using geotechnical data from the original ground investigations predict moderate embankment settlements occurring principally during construction. Settlement analyses based on all the available data predict far larger embankment settlements occurring over extended time periods. The latter analyses predict an embankment settlement similar to that observed and of sufficient magnitude to cause the observed lateral displacement of the bridge due to lateral loading of its piled foundation.
Maintenance and monitoring of anchorages: guidelines
Authors: Littlejohn S. , Mothersille D.
Published: February 2008

The maintenance and monitoring of permanent anchorages are important, particularly for anchorages installed over 30 years ago that may have been designed with inferior or inadequate corrosion protection. Following a review of tendon corrosion failures and observed anchor head conditions after 28–33 years of service in aggressive environments, guidelines on good practice for inspection, testing, maintenance and service behaviour monitoring are presented. Topics include designer responsibility, outer and inner anchor head inspection, component and material testing, grease assessment, monitoring with load cells, load lift-off checking using multi-unit and mono-unit jacks, on-site cyclic loading acceptance testing, anchor head design to facilitate monitoring, extent and frequency of inspections and service behaviour monitoring, and associated records. Current national, European and international recommendations are also summarised.
Intelligent Continual Right-Time Analysis of Field Data as a Service
Authors: Knabe S. , Shaw D. C. , Webb S. J.
Published: February 2008

This paper describes one application of Right-Time analysis of continual field measurements as used in a high-rate HPHT field in the North Sea. Many sensors and devices in the field are available for constant monitoring at the reservoir manager's desk, yet, we are still faced with the challenge of transforming all this raw streaming data into useful information. Data is regularly used to identify anomalies in the classical Field Automation sense. At medium-long term, however, it ought to be used to identify well and reservoir signatures that help in Formation Evaluation, and for reservoir management and planning. This rarely happens because the analysis involved – which includes highly technical disciplines – simply cannot be automated by computer. This makes it vital to be able to streamline these activities and to deliver the associated analysis as a turnkey service to the Field Operator.
Integrated Production Surveillance and Reservoir Management IPSRM — How Petroleum Management Unit PMU combines Data Management and Petroleum Engineering Desktop solution to achieve Production Operations and Surveillance POS business objectives
Authors: Abd Aziz Mariam , Kasim Mohamad , Som Mohamad , Gunarto Ronny , Lee Hin Wong , Ngu Chai King
Published: February 2008

The role of managing PSC's (Production Sharing Contractor) performance as the main function of PETRONAS's Petroleum Management Unit (PMU) poses challenges for Production Operations and Surveillance (POS) engineers to efficiently perform technical review and monitor performance of the fields across all Malaysian PSCs.

In order to address these challenges, PMU has embarked on an Integrated Production Surveillance and Reservoir Management project to implement a system that integrate cross-domain data into end users engineering software with a pre-defined surveillance workflow, processes, procedures and techniques. The objectives is to provide POS engineers with the required data and workflow templates at their fingertips to enable them to make quick analysis, hence, accurate decisions.

IPSRM implementation consists of two components. The first component involves the Data Management team to build the Data Hub to consolidate cross-domain data from PSC Operators. The second component consists of setting up the workflow and techniques templates in engineering software with online interface to the Data Hub. A unique hybrid Petroleum Engineering tools that combines parametric, user-driven and data driven analysis capabilities are introduced to allow full surveillance capability.

IPSRM implementation has been in operation and provides an effective way for PMU engineers to perform day-to-day surveillance analysis across Malaysia fields. Some benefits and achievements from IPSRM implementation are as follows: Reduced analysis cycle time of engineers by eliminating engineers' time in data preparation and processingPMU engineers are provided with a full spectrum of analysis capabilities to perform study and analysis, covering from user-driven, parametric to data-driven applicationsSome studies have successfully identified potential for recovery improvementNeural Network applications have successfully identified potential for injection/production optimization
ConocoPhillips Onshore Drilling Centre in Norway—A Virtual Tour of the Centre Including a Link Up With Offshore
Authors: Herbert Mike , John Aurlien , James Reagan
Published: February 2008

Integrated Operations can be defined as using information technology opportunities to change work processes to achieve better decisions, to remotely control equipment and related processes, and to move functions and operations personnel onshore as stated in the Norwegian White Paper, number 38, 2002 (St.meld. nr. 38, 2001-2002, Ministry of Oil and Energy)

Integrated Operations are often characterized by operational concepts where new information and communication technologies are used in real time to optimize offshore oil and gas exploration and production resources. This enables large volumes of data to be measured, sent to users via high bandwidth computer links that are shared amongst a broader user audience, and data that can be used to form better decisions.

Integrated Operations cover all aspects of business activities from Exploration to Drilling to Production though this discussion will focus on the Drilling aspects. For ConocoPhillips Norway (COPNo.) to employ this technology there has been a need to re-organize operations, to investigate new work processes and a need to establish a willingness to share information.

According to a study by the Cambridge Energy Research Associates in 20031, the increased use of new and emerging digital technologies could potentially boost world oil reserves by 125 billion barrels over the next 5 years. Petoro A.S. of Norway has estimated the added value of applying eField and Integrated Operations (IO) on the Norwegian Continental Shelf to be NOK 150 billion2. A more recent report by the OLF (Norwegian Oil Industry Association) indicates that the value of IO to Norway could be NOK 250 billion3. In summary, industry studies indicate that the potential benefits of IO are significant.

Five key digital technologies will substantially improve the oil industry's ability to see reserves more clearly, plan optimal drilling and production strategies and manage operations more efficiently. They are: Remote sensingVisualizationIntelligent drilling and completionsAutomation, andData integration.

This paper outlines the industry-leading experiences of the COPNo. drilling and well service group over the last 5 years from field-wide Integrated Operations.
Workover Rig Scheduling Using Reservoir Simulation
Authors: Lasrado Vineet Kevin
Published: February 2008

In this paper we will discuss the results of a prototype software application to view the rig schedule generated by a reservoir simulator. Visualization of simulation rig schedules and comparing with planned rig schedule would help in identifying opportunities to improve operations. With the help of the schedule chart and rig movement data, we better the schedule generated by trying to reduce the net distance traveled by the rig and reduce the number of rigs utilized. We ensure that the overall field oil production is not affected for all the cases.

Using reservoir simulation as a tool to assist in the rig planning and scheduling process has the potential to foster team collaboration between reservoir engineering, planning and operations team and facilitate better Integrated field management. The teams would appreciate the challenges associated with planning and scheduling activities for the field.
Walking the Line: Finding Balance Between Commodity and Custom Intelligent Completion Systems
Authors: Jackson Nielsen V. B. , Tips T. R.
Published: February 2008

For most of the ten years since market introduction, the majority of intelligent completion systems have been custom-designed and manufactured to meet the specific requirements of the customer. Customization was a natural step in the evolution of the technology, as operators tested usability and reliability in individual wells that reflected unique environments and challenges. Each situation was different, and the technology developed more or less in answer to those distinct demands (Figure 1); consequently, the experience base grew and the capabilities expanded.
Collaborative Working—People Issues in Perspective
Authors: Williams Paul
Published: February 2008

The accelerating growth in the construction and usage of collaborative environments designed to ensure that the oil and gas industry can have immediate access to scarce support and expertise has meant people in remote geographical locations have had to forge new relationships, acquire new intervention skills, and accept new ways of working.

This has raised many people issues, ranging from how to engage people in the necessary management of change programmes, the development of necessary behavioral protocols, through to acquiring appropriate leadership skills and installing appropriate recognition schemes, as well as the fundamental issue of how this new connectivity capability impinges upon existing communication processes.

Nowhere is this more acute, relevant and critical than in connecting the offshore operations community with their onshore support colleagues.

Drawing on real life examples the author surfaces, tackles and deals with these issues, showing how collaborative environments can be used to produce a high performance one-team culture.
Modeling Flow Profile Using Distributed Temperature Sensor DTS System
Authors: Wang X. , Lee J. , Thigpen B. , Vachon G. , Poland S. , Norton D.
Published: February 2008

Distributed Temperature Sensing (DTS) technology uses fiber-optic cable to measure continuous temperature profile along the wellbore. Measurement interpretation can provide valuable information, and one of them is real time flow profiling that helps to monitor the fluid flow in wells. This valuable information can assist real time production decision with no well intervention. However, the complexity of the data analysis limits the use of DTS as a flow allocation technique.

This paper presents a new flow-profiling model using DTS technology. The model is based on steady-state energy balance equation and it handles multiple production zones with its own zonal fluid properties. The model is applicable for gas and oil wells in onshore and offshore environment. The model is integrated into easy-to-use software and it can be run in two modes: forward simulation and flow profiling. The forward simulation calculates temperature distribution along the wellbore for any given production profile, and this mode is critical for the model calibration. It is also very useful for emulating what-if scenarios, like water breakthrough. The flow profiling estimates production profile based on measured temperatures, which is the base for the real time well monitoring.

Our studies with the model show that geothermal profile, fluid properties, formation properties, well completion, and deviation as well as Joule-Thomson effect all play key roles for the model accuracy. Joule Thomson gas cooling effect only occurs at lower pressure while reversal appears at higher pressure region.

The model is tested against synthetic, literature and field examples and good agreements have been obtained. Test results have been presented.
Optimize Well Performance with Electrical Wireline Interventions
Authors: Kruger C. , Schwanitz B.
Published: February 2008

In recent years, re-invention and development of electrical wireline mechanical applications, initially for high-angle well-access in conjunction with wireline tractors, has proven able to unlock value potentials by allowing interventions, previously thought impossible or cost prohibitive, even in low angle wells. Common denominators are remote-control, rig-less operations and documented large value-creations.

The most recent advancement in this service category includes milling and drilling on wireline; a breakthrough within intelligent production optimization. With the ability to engage a wide variety of challenges downhole, this technology provides hitherto unseen possibilities to increase production quickly, efficiently and safely. Also representing new capabilities is the technology of transforming constant mechanical force independently of the wireline and depth/deviation of the well. The advantage here is that operations can be performed from a crane or mast unit with electric line and apply a pulling/pushing force capable of manipulating down hole production control devices in a controlled and repeatable manner.

This paper will present innovative areas of recovering production through various case histories.
Improved Efficiency & Knowledge Based Support of Oil Well Drilling through Cased Based Reasoning (CBR) Approach
Authors: Islam Aminul M. , Skalle Pål
Published: February 2008

As of today, no well is drilled without problem. Oil and gas companies spend about $ 25 billion annually on drilling. Unfortunately, not all of that money is well spent. A significant portion, about 20% is attributed to losses. These include loss of materials & drilling process continuity. In particular, wellbore stability related problem remedy cost is substanting and such problem are repeatedly occurring but still so complex that they are not easily solved. The necessary experience obtained by individuals or by the organization is difficult to transfer efficiently to those that need it. The objectives of this paper is to a problem analysis method called Case Base Reasoning(CBR) and its application in terms of a new level of active computerized support for information handling, decision support for wellbore instability cases and prediction of potential unwanted events in the drilling engineering domain.

CBR is well suited for dealing with the complexity of wellbore stability problems, and the large number of parameters involved, experience is stored in cases which are linked to a model of general domain knowledge. The general domain knowledge is containing information with explanatory support to case knowledge. A knowledge Tool named "Creek" (research version) has been used here to create the ontology framework.

This paper mostly addresses how to make a case from real case data, create symbolic entities including case retrieval methodology and finally diagnosis similar problem cases.The cases resented are all related to improving the drilling plan, in such a way that the problem can be planned away throughts the next drilling plan. The resulting outcome from pased cases acts as input for making better drilling plan to avoid similar problems in the future.
Meeting the Challenges of Real Time Production Optimization— A Parametric Model-based Approach
Authors: Awasthi Ankur , Sankaran Sathish , Nikolaou Michael , Saputelli Luigi , Mijares Gerardo
Published: February 2008

The challenges to achieve real-time production optimization (RTPO) of oil and gas fields lie in the integration of asset-wide operations at multiple time scales, knowledge of reservoir phenomena, and efficient data management. Traditional approaches to production optimization workflows often make simplifying assumptions and work within artificial boundaries, to lower the complexity of an all-encompassing optimization problem. While this decomposition creates manageable workflows, it does not adequately support the integration of production optimization at multiple levels.

We propose a methodology to achieve hierarchical decomposition of the overall production optimization problem at different time scales, where real-time data are consistently used to identify reservoir performance and optimize production. The optimization tasks at each of these levels are organized through automated transactions of targets, constraints, and aggregate measurements. For example, strategic decisions such as long-term (e.g., yearly, monthly) injection targets, production plans etc. calculated using a full-physics reservoir model are resolved into tactical decisions for short-term (e.g., weekly, daily) production planning.

A moving-horizon based parametric model is proposed to provide fast predictions for production optimization in the short-term framework. Since the model structure is based on the decomposition of a full-physics reservoir model, it is reasonable to expect that the parametric model will be robust enough to be used for extrapolation outside the range of history data, a property needed for optimization purposes. In this paper, we present an analysis of the structure of the physics-compliant empirical model, the model's range of applicability, techniques that can be used for parameter identification, and use of the model for short-term production optimization. The paper presents a number of case studies to illustrate the benefits of the proposed methodology and its application in typical workflows for closed-loop reservoir management.
Progress in Integrated Operations Centers
Authors: Landgren Kenneth , Sood Sanjaya , Veeningen Daan , Berge Rolf
Published: February 2008

Oil and gas companies increasingly require environments that support real-time E&P business processes, where wellsite information, applications, and experts can be linked with operational managers and decision makers in one place so that daily operational parameters can be viewed and decisions executed. Most companies believe that making decisions in real time while leveraging global resources and infrastructure will help to improve their field productivity while reducing costs.

Project team members are often collocated to ensure open communication and planning. However, since E&P activities often take place in remote and hostile parts of the world where it may not be possible or economical to deliver all the required resources and personnel, global operations with dispersed personnel frequently require such operations support centers to be "virtualized." Reliable and secure information flow is central to ensuring success in the contemporary oil field.

In a previous paper, the authors outlined the significant challenges of process, networking, security, hardware, and software infrastructure encountered in creating and supporting these integrated operations centers. These challenges include the end-to-end IT infrastructure such as wellsite and field IT, the design of the work processes to be supported, and the business model for company implementation.

This paper discusses some of the progress that has been made in meeting these challenges over the past year, with particular focus on the actual applications that support oilfield operations.
Metrics for Economic Evaluation of Innovative Technologies in the Oil Industry
Authors: Marsala Alberto F.
Published: February 2008

Technological innovation is a key factor in an oil company's bottom line.

Not only is it a tool for operational process improvement (cost reduction, production, and reserves increase) but also a driver for the company's relational marketing. The intangible components of technological innovation, if properly evaluated and managed, are key drivers for know-how development, technological leadership, and reputation building.

These are crucial factors for staying in business in a world in which it is essential to demonstrate ability to control complex problems (e.g., exploitation in challenging areas, new energy scenarios, environmental, safety, and social constraints, etc.).

These are key issues vis-á-vis stakeholders, partner companies, producer countries, and the global community. Effective business management and performance improvement require quantitative analysis; in other words: never measured, never improved. This paper presents a methodology for the economic impact valuation of innovative technologies in the upstream oil industry. Both tangible and intangible components of an innovative technology contribute to generate value and thus each of them is to be considered as a very concrete point that requires comprehension, valuation, and management.
WITSML Changing the Face of Real-Time
Authors: Deeks N. R. , Halland T.
Published: February 2008

WITSML is a key enabler in an increasing number of real-time workflows. This is particularly true for integrated operations within the growing numbers of onshore operations centers. Two years ago WITSML was a technology known by few and actively used by even less. Now the SIG steering the standard has grown to 51 companies.

The starting point for most companies in using WITSML is to bring depth data into their asset databases. For many this has become the norm. Early adopters like Statoil are broadening their use into a wider range of wellsite operations. Within asset teams a standard data delivery mechanism allows integration of new tools and workflows, letting Geologists and Engineers make use of real-time data within their familiar desktop applications. It also enables centrally managed data delivery services letting them focus on their areas of expertise, not data gathering.

New technology and processes in these areas are helping operators make the next big step from real-time remote monitoring to real-time remote control.

For growing numbers it is now not enough to receive a visual representation of the data. They expect data to be delivered in real-time via a standard format.

WITSML also brings operators the opportunity to standardize data delivery workflows, to clarify contractual requirements to providers and to establish and measure realistic data delivery KPIs.

Within Schlumberger WITSML enabled workflows are well established, answer products for drilling optimization and interpretation utilize the standard via a unified WITSML client. This reduces software development cycle time and simplifies data gathering.

WITSML is becoming established, bringing proven advantages to real-time workflows. Continued uptake of the standard will enhance the competitive advantage of service companies and the operators utilizing it. WITSML is here to stay and should be supported more widely within the industry.
Measuring Development and Adoption of New Oilfield Systems Using Technologies With Real-Time Capability
Authors: Veeningen Daan , Kanvinde Sanjay , Coffin Guillaume , Udezue Olisa
Published: February 2008

If a brand-new oilfield product or service becomes widely used in less than a decade, that's fast. The fact is that the petroleum industry is one of the most conservative when it comes to adopting new technology. This paper proposes and describes the use of a capability adoption index to benchmark and measure the development and adoption level of oilfield systems with real-time capability.

The capability adoption index is a tool for measuring and managing the advance of real-time technology in the industry. The application tracks incremental change and provides a roadmap for technology development and adoption. There are three main reasons for deploying systems with real-time capability. First is the growing shortage of skilled professionals. Second is the need to operate in harsh or environmentally sensitive regions, where monitoring and controlling operations from a distance can improve safety and limit the environmental footprint. The third driver is that systems that feed back data in real time may increase production by allowing operators to respond quickly to changing conditions in the well.

The 10-level index provides a bigger picture of the maturity of real-time technologies within the global market. The different levels of technology adoption are illustrated both for geographic areas and for different services. The roadmap towards autonomous automation provides more efficiency and profits for the operating company. For service companies, the ability to drill, test, operate, and control wells with real-time capability helps maintain the quality of service delivery. It creates more efficiency for people and systems.

In the industry's journey toward autonomous automation, the significance of the index is a measurement allowing companies to look back at their progress, manage change, and plan the road ahead.
Extensions to and Roll Out of Data Driven Production Surveillance and Optimization
Authors: Moncur C. E. , Jakeman S. , Berendschot L. , Cramer R. , Briers J. , Stroobant F. , Ahmad R. , Goh K. C.
Published: February 2008

Oil and gas production from a cluster of wells is conventionally relatively difficult to manage, at least partly due to field conditions, subsurface uncertainty and the multiphase nature of the well effluents. This can lead to late diagnosis of production problems, slow and conservative handling of production constraints and restricted understanding of subsurface potential. FieldWare Production Universe (FW PU) is a software application developed by Shell International Exploration & Production and Shell Global Solutions International that allows data driven well models to be constructed and updated from real time production data, and thereafter applied to track well-by-well production in real time. This paper updates on extensions of FW PU data driven techniques and also on the experience so far on the wide scale field implementation, roll out and support of the technology.

The successful embedding of a real time technology that such as FieldWare PU, which allows a step changes in the level of surveillance of well-by-well production, and the realization of maximum value from its use is a non-trivial exercise. In an ideal implementation, the software application needs to match the dynamic physical production elements (reservoir inflow, well performance, production processing and testing facilities) and the capabilities of the production staff as well as their production management processes. Key elements of the FW PU roll out in field operations include evaluation of actual production surveillance challenges vis-à-vis the value of the tool to be introduced, hardware and software readiness checks, clear setting of goals and expectations, post implementation evaluations, training of users and super-users, adjustment of workflows, and embedding the use of the application into the relevant operational processes.

This paper further discusses extensions of the data driven approach to a wide spectrum of applications, including real time operational optimization, the tracking of well productions in subsea and smart wells, and for specific types of production operations such as for beam pumped wells as well as wells which are intermittently operated. In particular the application of data driven techniques to beam pump pump-off controls, circumventing the need for load cells, is highlighted.
"If Tesco can do it why can't we?": The Challenges and Benefits of Implementing RFID and Mobile Computing in Upstream Environments
Authors: Morris Carl
Published: February 2008

We live in a fast moving consumer world where pocket PCs are common place and auto-identification technology is everywhere - mainly barcoding but increasingly Radio Frequency Identification (RFID). So why isn't Upstream Oil and Gas adopting these technologies at a faster rate to improve business performance? "If Tesco can do it, why can't we"?

This paper examines the major applications for the use of hand held devices (HHDs) and auto-identification within supply chain, maintenance and operations. It describes the benefits in terms of the ability to link offshore and onshore operations more effectively and accurately pass real-time or near real-time information between assets, support organisations and supply chain partners, to allow earlier and improved decision quality, as well as the traditional efficiency gains. Upon detailed analysis, moderate investment yields high potential returns.

One of the fundamental differences between the supermarket chains and the Oil and Gas industry in this area is the lack of agreed technical standards in terms of RFID hardware and data transfer standards, acting as a barrier for supply chain integration. This paper touches on the work that is underway to address this issue, but goes on to explain how an appropriate application of technologies and attention to process and change management considerations can deliver robust solutions for operations and maintenance today.
Design of Visual Facilities Within Collaborative Decision Environments
Authors: Clark Alex
Published: February 2008

"How big does the screen need to be"? This was the innocent first question asked near the beginning of a deployment of multiple collaborative decision environments (CDE). Slowly, the complexity of the problem surfaced as we were forced to consider the following questions: What are the limits of current display technology?How will people be seated in the physical space and how many seats are required?What is going to be on the display? How can we use that space most effectively?

A large quantity of information exists from vendors detailing the optimum size of display and placement for a television or cinema screen. A large body of data exists for individuals using computer monitors. Each has very different usage characteristics.

CDEs created a scenario that falls between these extremes — computer display characteristics (able to clearly read data) within a group environment (like a cinema). The display itself will be divided into sections, effectively providing users with a matrix of individual computer monitors that need to be examined both individually and as a whole.

To achieve this, there was a need to go back to first principles and answer some important questions. What is 20/20 vision? What are the ergonomics of the eyeballs, neck, and body? What types of information exist and how is it visualized? The final solution needs to be deployable in the office, to locations offshore, and perhaps even in a portable environment to teams ranging from a single user to 10 or more.

This paper examines this problem and provides some methodologies about how to determine the best display for a facility and where to place users within a room so that they can see clearly the full extent of the display. It also explores how this information should be laid out to maximize the usefulness of the display area. This information should prove beneficial to future CDE designers.
Downhole Multiphase Metering In Wells By Means Of Soft-sensing
Authors: Leskens M. , de Kruif B. , Belfroid S. , Smeulers J. , Gryzlov A.
Published: February 2008

Multiphase flow meters are indispensable tools for achieving optimal operation and control of wells as these meters deliver real-time information about their performance. For example, multiphase flow meters located downhole can improve the production of multilateral and multizone wells by timely allocating the zone where a gas or water cone occurs. However, multiphase meters are either expensive, inaccurate, or cannot be used downhole due to the harsh conditions. An alternative that can be used to overcome these disadvantages is to use multiphase soft-sensors, i.e. to estimate holdups and flow rates from relatively cheap and reliable conventional meters, such as pressure and temperature measurements, and a dynamic model connecting these measurements with the unknown quantities. The aim of this paper is to demonstrate, via two simulation based case studies, some possibilities and limitations of such multiphase soft-sensors. In the first case study the question is adressed whether it is possible to use only downhole pressure and temperatures measurements to estimate in real-time the water, oil and gas flow rates in a well. This question is of practical importance as these measurements are relatively cheap and reliable. The second case addresses the question whether it is possible to allocate the gas cone in a well with multiple inflow points or zones. This question is relevant as the estimated flow rate and holdup profiles can be used to manipulate Inflow Control Valves in such a way that gas breakthrough is prevented.

Using amongst others OLGA data as "real-life" data, an additional question addressed here is what the influence is of soft-sensor model error and measurement noise on the quality of the estimates.

From the first case study it can be concluded that, due to bad observability, pressure and temperature measurements alone are not sufficient to accurately estimate in real-time well flow composition parameters in a practically relevant situation. The preliminary results discussed in the second case study indicate that a soft-sensing solution to the gas cone allocation problem may very well be feasible.
Real-Time Integrated Field Management at the Desktop
Authors: Issaka M. B. , Dahan M. W. , Alburaikan M. M. , Verjan E. A.
Published: February 2008

Accurate individual well production rates are essential to meet corporate production target plans, optimize reservoir performance and make reservoir management decisions that may require well intervention. Short of installing rate measurement devices on each well, a "back allocation" method is generally employed to assign well production rates, using multiplying factors based on well tests conducted the month before. Apart from the inherent errors, based on the assumption that the wells produce at the same rate throughout the month, the process is also not suited for real-time field management that requires production rates to be known much more frequently.

This paper describes the implementation of a system that automates the calculation of individual well production rates using real-time pressure data from permanent sensors installed on the wells. The system, based on integrated physical models of the reservoir, well and surface network, has been successfully used to implement crude blend management in a large Saudi Arabian field, producing from three different reservoirs. The paper also describes how the system is used to automate the validation of well test measurements, allowing the engineers to focus their time on problem wells while ensuring that all wells are reviewed. In addition, field models are kept evergreen and can be utilized by different disciplines for production forecasts.

Application of the system could result in significant cost savings, due to reduction in the requirements for physical metering of well production. The system also provides unique optimization opportunities, allowing the engineer to determine the optimum settings to maximize production or revenue. Other benefits include, faster resolution of production problems due to early problem detection, focus on exceptions rather than bulk and massive troubleshooting, and zero-latency application-assisted decision making, all combining to bring real-time field management and optimization to the engineer's desktop.
Information Technologies That Enable Human Competence Development and Assurance
Authors: Omar Samir , Al Hosani Hassan , Moore Robert L.
Published: February 2008

Description of the Material

This paper describes the experience of an Abu Dhabi upstream operating company in the implementation of a competency assurance system for entry-level employees. The implementation and tracking processes which form the core of the system were designed with project management and engineering principles in mind. They therefore lend themselves to the technologies that project managers and engineers use, such as databases, project planning systems, and graphical reports and scorecards. The company's use of these technologies based on coupling clarity of business requirements with simplicity of IT solutions resulted in a rapid and successful implementation of the competence assurance system.

Application

This material is applicable to organizations considering or implementing a competence development and assurance system.

Results, Observations, and Conclusions

The methods described in this paper, derived and proven in practice, have helped the company:

As a result, the company has achieved a high success rate in moving employees through the system quickly and efficiently.

The paper will also describe how the engineered approach alone is not enough when developing human competencies. Effective marketing, leadership, reward, and knowledge management systems are also critical to successful implementation.

Significance of Subject Matter

As oil and gas companies strive to achieve performance excellence and meet tough HSE goals, the challenge faced by all is to find, develop and retain competent people. This challenge is magnified as the current employees' demographics alert high risk of skills dilution and when advances in technology drive renewed development efforts. Competence assurance processes that are structured, systematic, and measurable are important tools for companies to use for achieving this desired result.