bluuebunny/crossref_metadata_2025_split huggingface dataset:
Development of an Integrated Metrics Reporting Tool to Monitor and Optimize Performance of the Greater Burgan Oil Field in Kuwait
Authors: Desai Sameer F. , Abdulla Farida , Gazi Naz H. 
Published: December 2009

Abstract
Greater Burgan is the second largest oil field and the largest clastic reservoir in the world. There are over 1000 wells on production in this field. There is a robust plan to drill more wells in the coming years to cater for world demand in production. It is therefore necessary to track and report the production and field performance from this giant field in a timely and effective manner. This paper describes the approach taken towards the development of an integrated tracking and reporting metrics tool which displays operational data to key decision makers to monitor field performance and make practical decisions.
The metrics report provides a comprehensive view of the performance of an asset using key performance indicators (KPIs) in the form of a dashboard. Information is captured from corporate databases, in house tools and data sources tracking daily operations. The report is displayed graphically for quick overview of categories such as daily production, subsurface and shut-in well potential, facility capacity and constraints, well work, production tests, surveillance activities, wet and dry completions, production allowables, and other pertinent highlights through a single visual interface.
Designed as a scorecard the tool provides a platform for increased collaboration and knowledge capture between assets. It reduces time spent looking for data thereby allowing more time for higher priority issues. The impact is directly on the reservoir management strategies, production management, prioritization of well work and surveillance activity.
The metrics report is a best practice implemented by KOC Field Development South East Kuwait Asset Group to monitor the Greater Burgan oil field performance and optimize its production. Value added decision making is made easy wherein plans are properly implemented and targets are met. The designing, completing, and operating aspects of this successful reporting tool are highlighted together with the challenges and accomplishments.
Integrated Solutions for LNG Plants System Studies: Simultaneous Simulation of Electrical and Steam Systems
Authors: Lerch Edwin , Fehn Thomas , La Seta Piergiovanni , Tomschi Ulrich 
Published: December 2009

Abstract
In the last decades the importance of LNG (liquid natural gas) has been increasing continuously. Worldwide a large number of plants have been erected using classical compressor technology driven by direct-coupled gas turbines. This approach limits the availability due to maintenance restrictions and the missing spinning redundancy. Modern concepts are based on large full electrical compressors which allow controlling the process with reduced energy consumption. The corresponding maintenance concept improves the LNG plant availability significantly.
LNG plants generally have no grid connection, i.e. the LNG plant must be supplied under island conditions. Guarantee a high availability of the electrical and steam generation is however necessary. Therefore it is primarily important not only to provide a suitable system design, but also to investigate its ability to dynamically withstand heavy events, taking into account the mutual interaction of electrical output of the steam turbine and the variation of the steam demand, the boiler capacity and the dynamics of the supplementary firing.
Aim of this paper is to illustrate an integrated approach for the steady-state and dynamic study of LNG plants, in which both the electrical and the steam system are completely modeled and interfaced. After separate design, both systems are simulated with the same simulation tool, so operations and events are immediately incorporated and the two systems show the reciprocal interaction. Thus more realistic and significant system responses to events are obtained, with increase in the project efficiency and reduction of investment costs.
To validate the approach, a typical LNG plant is modeled, including all relevant equipment and controllers, as well as process system units, with PSS®NETOMAC. The simulation of severe outage cases allows to optimize the basic electrical and steam control concept and to design the load or generation shedding sequences, depending on the outage severity.
Bioremediation of Crude Oil Contaminated Soil by Composting using Wood Shaving as Bulking Agent
Authors: Ahiamadu Nnamdi Michael , Suripno S. 
Published: December 2009

Abstract
Oil exploration and production activities can cause severe environmental damage due to crude oil discharges to the environment. Remediation of impacted environment follow a general framework hinged on legal/regulatory framework and site specific risk assessment of the levels of contaminants present. Within this general framework of regulations, site specific constraints and cost-effectiveness, the best available technique (BAT) for remedial actions is usually proffered. In this study case of crude oil contaminated soil remediation, composting of the contaminated soil in bio-piles using wood shavings (saw dust) as bulking agent and a commercial product as source of both commercial microbial inoculums and nutrient (N, P, K), was adopted. The major activities in this project involved composting in windrows, broadcasting of the nutrient source and laboratory monitoring. The Total Petroleum Hydrocarbon (TPH) degradation was most rapid during the first 5 weeks of the remedial activities and thereafter followed a typical first order degradation curve. After, 22 weeks of treatment 93% from 3830mg/kg dry weight to 268.1mg/kg dry weight degradation of TPH of the contaminated soil was achieved and a corresponding increase in number of bacterial populations was also observed.
Rapid Prediction of Carbon Dioxide Adsorption Isotherms for Molecular Sieves Using Simple Correlation
Authors: Bahadori A. , Vuthaluru H. B. 
Published: December 2009

Abstract
CO2 emission from burning fossil fuels has been identified as the major contributor to the increase in atmospheric CO2 levels that can potentially lead to global climate changes. Among main methods that are being developed for CO2 capture and separation, carbon dioxide adsorption is of great interest due to its low energy consumption, low equipment cost and easiness for application. In this work, a new simple-to-use correlation, which is easier than current available models involving a large number of parameters, requiring more complicated and longer computations, is presented to predict accurately the carbon dioxide adsorption isotherms for a molecular sieve as a function of temperature and carbon dioxide partial pressure. This correlation predicts the carbon dioxide adsorption isotherms for carbon dioxide partial pressures and temperatures up to 120 kPa and 470 K respectively. The promising method to develop correlation for accurate prediction of carbon dioxide adsorption isotherms could be extended for CO2 capture and separation for the wide range of adsorbents including various molecular sieves just by readjusting the tuned coefficients. The average absolute deviation between reported data and the proposed correlation is around 4%. Simple-to-use approach can be of immense practical value for the Engineers and Scientists to have a quick check on adsorption capacities of a given adsorbent at various temperatures and pressures without performing any experimental measurements. In particular, personnel dealing with regulatory bodies of greenhouse gas abatement, process industries would find the proposed approach to be user friendly involving no complex expressions with transparent calculations
Subsea Separation and Boosting—An Overview of Ongoing Projects
Authors: Gruehagen Henning , Lim Dennis 
Published: December 2009

Abstract
Subsea processing is one of the most interesting technologies currently being introduced into the oil and gas industry. Treating the production flow at the seabed opens up opportunities to achieve more effective deployment of oil and gas reservoirs in all regions around the world. Among these are Tordis in the North Sea, BC-10 in Brazil, Perdido in the Gulf of Mexico and Pazflor in Angola. All of these projects include subsea separation and boosting.
For BC-10 and Perdido, gas/liquid Caisson separators with a length of approx. 100 metres are utilized together with Electrical Submersible Pumps (ESPs) to enable and boost production from deep water reservoirs.
The Tordis Increased Oil Recovery project realizes the first commercial full scale subsea separation installation in the world. By separating out water and sand at the sea floor and injecting this waste into a dump reservoir in a closed loop system.
The successful installation and start-up of the Tordis Subsea Separation Boosting and Injection system and the Perdido gas/liquid Caisson separators, subsea processing is now taking its first steps into the future.
The common view is that there will be many applications for subsea processing as the technology matures and gather more widespread acceptance. With the oil industry running out of oil that is easy to produce, means that producing oil and gas from offshore fields in deeper waters and in more remote areas is inevitable.
Considerable efforts are being made in the area of subsea gas compression, which has great potential and could save cost of additional surface infrastructure where compression is needed to continue production of maturing gas and longer step-out fields.
Although the solutions for these projects are different, many of the technological challenges are similar. A brief overview of the technological challenges for these projects will be presented, together with recent developments within Subsea Processing.
Utilizing UBD Technology for Future Development of Parsi Oilfield, Challenges and Opportunities
Authors: shadravan Arash , Nabaei Mohammad , Amani Mahmood 
Published: December 2009

Abstract
Underbalanced drilling is considered as one of the main recommended technologies for further development of Iranian depleted fractured carbonate reservoirs. Parsi is one of the most depleted oil fields located in south western part of Iran which started to produce with initial pressure of 3,800 psia in 1966. In 2001 the reservoir pressure was 3,000 psia with 1.48 Billion STB cumulative production. By June 2009 some1.68 Billion STB had been produced with the current reservoir pressure of 2,470 psia at 1,800 meters subsea. The serious challenge in this field is dealing with the complete losses in drilling operation. Also high production rate has increased GOR and caused gas coning. National Iranian Oil Company (NIOC) has initiated UBD technology program since 2005 in southern Iranian depleted fields. The key aspects for utilizing UBD in Parsi oilfield have been: avoiding complete losses and reservoir impairment, improving rate of penetration (ROP), drilling performance and reservoir fracture productivity. This paper evaluates the advantages of UBD in Parsi oilfield and summarizes practical solutions not only to overcome the challenges happened during the UBD implementation but also to gain more financial returns in drilling a well in this field. Data and experiences of OBD and UBD wells in Parsi field have been used as a basis for this study.
Seismic EOR—The Optimization of Aging Waterflood Reservoirs
Authors: Kurawle Irfan , Kaul Mohit , Mahalle Nakul , Carvalho Vickey , Nath Neelendra , Amin Zohaib 
Published: December 2009

Abstract
The majority of enhanced oil recovery projects currently underway are based on Water floods which are known to provide lesser recovery compared to other recovery mechanisms. Many such reservoirs exist where the recovery has been less than 30% altogether due to various drawbacks of the conventional Water floods. The paper would like to discuss a new EOR technique using Acoustic and Seismic energy to reduce interfacial tension and promote coalescence of oil ganglia using the resonant frequency principle. The technique uses pressure and sound waves at pre-determined frequencies to set the oil molecules in motion to promote coalescence and thus reducing the fingering effects. The flood pattern can be optimized by recovering oil from previously unswept areas. It thus enhances the life of the primary flood providing valuable economic savings. The process can also be applied to various reservoirs in their tertiary recovery phase to extend the life of the project. Experiments conducted in the lab show that the frequency of oil and water may differ from reservoir to reservoir and compositional analysis of samples is required to determine the resonating frequency. The design of the downhole tools for injector wells to implement this technique are also discussed briefly.
Statistical Method for Detection of Poor Hole Cleaning and Stuck Pipe
Authors: Gulsrud Thor O. , Nybø Roar , Bjørkevoll Knut S. 
Published: December 2009

Abstract
During drilling operations poor hole cleaning may result in low drilling efficiency, stuck pipe, problems with well control or even a loss of the wellbore. In this paper a method for warning of poor hole cleaning and stuck pipe is proposed. The method is based on correlating statistical features calculated from bottom hole or stand pipe pressure and torque signals. Especially, the correlation is performed by multiplying the third order moment of bottom hole or stand pipe pressure time series and normalized standard deviation of torque time series. The correlated signal is used as input to a warning generation scheme. This scheme is based on detecting the sign of the correlated signal samples within a moving time window. If the number of positive samples exceeds a predefined threshold a warning is raised. Results of an experimental study on data from three different wells indicate that the proposed statistical method can provide early detection of poor hole cleaning and stuck pipe.
Improvement of Safety Instrumented System (SIS) Performance through Detection Diversity
Authors: Naranjo Edward , Choo Edwin , Kornbech Mads 
Published: December 2009

Abstract
Detection coverage plays an essential role in defining the capacity of a fire and gas system to perform properly when required (ISA-dTR84.00.07 2008). The concept seems clear: As the probability of a sensor detecting a hazard increases, so does the likelihood that fire and gas systems (FGS) are able to mitigate more severe consequences.
Several reports document the importance of detection coverage. Statistical studies of hydrocarbon gas releases by the Health and Safety Executive (HSE) calculate the detection rate of gas detectors at 60% (HSE 2000) and 76% (HSE 2003a). Another report by the same agency on gas turbine incidents between 1991 and 2004 puts gas detection coverage at about 78% (HSE 2008). The collected historical record suggests that, even if an FGS design complies with a high safety integrity level (SIL) target, a reduction in risk is not achieved unless detector coverage is high. An independent calculation of risk reduction under different scenarios of detection coverage supports the empirical findings (Choo 2008).
An important, but often neglected element of detection coverage is the contribution of applying two or more sensing technologies toward risk reduction. Detection diversity improves the odds that a hazard is detected early on, independent of the number of detectors installed, their reliability, and geographic coverage. Diversity is often effective, because detection methods share few common failures. By drawing on the advantages of each, several different types of detectors can be more effective at mitigating the spread of an accident sequence than any one type alone.
In this report we examine how fire and gas detector coverage can be improved by means of detection diversity. The study applies Markov models to illustrate the potential risk reduction as a function of detection diversity. Monte Carlo simulations are also used to estimate the contribution of detection diversity on attaining a specific SIL. The results confirm that field devices have a substantial effect on SIS performance. The paper concludes with recommendations on the application of several detection technologies to protect offshore facilities. Note: This paper is not about whether or not FGS can be considered part of a SIS. The authors understand the arguments for and against this.
Making Friends with Your Computer—A Participatory Approach of the Workstation Ergonomics Program
Authors: As Safira Elsye , Syamsu Mariena , Darmawan Eric 
Published: December 2009

Abstract
Employees working in the office tend to underestimate the potential safety and health hazards in their immediate environment, including their computer workstation. Although most workers spend a large amount of time working with computers, they still possess a poor understanding of ergonomics and human-computer interaction. Health risks, such as MSD (Musculoskeletal Disorders), visual fatigue and mental stress can lead to severe health impairments i.e. Carpal Tunnel Disorder (CTD). These health problems do not appear overnight but only over a considerable period of time.
The participatory approach is one of the methods used for the ergonomic workstation program. This approach involves each department Champions conducting Display Screen Equipment (DSE) coaching sessions, which are followed by the completion of a self-assessment form by each DSE user in their departments. This self-assessment is important to ascertain the frequency of health symptoms related to MSD as well as the percentage of factors that contribute to health risks experienced by the DSE users.
In addition to the statistics obtained, the other important part of the assessment is focusing on actions to be taken to minimize DSE health risks. These action items will be followed up through personal coaching sessions to fine-tune behavioral approaches and deploy appropriate equipment to ensure that the most optimal ergonomic workstation designs are implemented. The key to making this program a success is to encourage multiple departments to actively participate.
Multilayered Reservoir Stimulation: Case Study of Effective Acid Diversion Achieved Using the Associative Polymer Treatment Diverting Agent in Khuff Carbonate Reservoir Wells in Saudi Arabia's Ghawar Field
Authors: Núñez Walter , Leal Jairo , Malik Ataur , Solares J. Ricardo , Sierra Leopoldo , Izquierdo Guillermo 
Published: December 2009

AbstractOne of the key objectives of all acid stimulation treatments in multilayered reservoirs is to achieve effective diversion so that acid is equally displaced throughout all hydrocarbon bearing zones. The highly heterogeneous nature of the multilayered high-pressure/high temperature (HPHT) Khuff carbonate reservoir, the significant depth separation between layers, and the sour characteristics of the gas and condensate deposits in Saudi Arabia's Ghawar field present a complex technical challenge when attempting an effective stimulation and diversion.The Associative Polymer Treatment (APT), which is a water base diverting agent formulated with a very low viscosity that allows effective fluid diversion during stimulation treatments, has been successfully field tested by Saudi Aramco. Three matrix acid stimulation treatments, comprising an organic blend, retarded acid, nitrogen and the APT diverting agent, were successfully implemented in wells completed in the Khuff carbonate reservoir with perforated intervals upwards of 260 ft. Clear diversion and acid reaction signatures have been observed in the surface and bottom-hole pressure (BHP) data recorded throughout the treatments. Data analysis of the post stimulation pressure buildup (PBU) test conducted in one of the treated wells showed a skin factor of −4.3. Additionally, production logging tool (PLT) surveys conducted in two of the treated wells showed flow contribution from all the perforated layers, which contrasts with offset producers previously treated without the diverting agent, showing the largest contribution coming from a single perforated layer. More than 40% poststimulation gas rate increase has been observed in the treated wells.This paper discusses the rationale for selecting and field testing the APT diverting agent, and provides details about the acid treatment designs, highlights implemented treatment optimization steps, discusses treating pressure behavior and lessons learned throughout the treatments, and provides zonal contribution and post-stimulation test results evidence confirming the effectiveness of the APT diverting agent.
Practical Aspects of Integrity Management for Large Oil and Gas Production Infrastructures
Authors: Ciaraldi Stephen W. 
Published: December 2009

Abstract
Major accident prevention and production reliability are among the top priorities for upstream oil and gas operations. Effective Integrity Management (IM) is a fundamental requirement for achieving these objectives. For large and aged production infrastructures, substantial people and money resources are required for effective IM, in addition to practical implementation strategies and tactics. Observations on implementing IM for large infrastructures are described based on the author's experiences with offshore production operations in Egypt, Trinidad and Indonesia.
The observations start with development of IM strategies aligned to the business and the deployment of risk based evaluation tools to set priorities and implementation targets. Experiences defining execution tactics which fully consider people and money resource limitations, competing business objectives and activities, contracting requirements, materials limitations and logistics constraints are noted. Organizational aspects and interfaces are discussed, as are important aspects of safety management, planning, scheduling and implementation tracking using ever-evolving key performance indicators (KPIs). Finally, the role of regular status reviews and external audits are noted with respect to continuous improvement of IM programs.