bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enhancing The Value of The Irong Barat Field through An Integrated Team Approach
Authors: Bin Yusoff Emry Hisham , Cheng-Sun Ong , Chakravarthy S. , Jamiran Mohd Khalid 
Published: December 2007

Abstract
Irong Barat Field, located in the southeastern part of the Malay Basin, was discovered in 1979. The field structure is a complexly faulted WNW-ESE trending asymmetrical anticline dissected into four major fault blocks by a set of NNW- SSE trending normal faults, with additional subsidiary faults further segmenting the field in the central fault blocks. Oil bearing reservoirs are encountered in the H and I reservoir groups, with the bulk of reserves and present production from the H-50 unit. Existing development, 18 wells from a manned Irong Barat A platform, is mainly confined to the structurally less complex Fault Block I with 2 wells completed in the adjacent Fault Block II. Production started in November 1983 and more than 80% of the estimated developed reserves have been produced. Currently the field is producing at 11 MSTB/D.
A multi-disciplinary team was formed to identify and mature the hydrocarbon potential of the complexly faulted undeveloped Fault Block II, III and IV and also the remaining opportunity in Fault Block I. The 3D seismic, appraisal well, production and well data were reviewed and a few development options were considered. As a result of the integrated field review, 2 additional drilling programs are planned to further develop the field, which involve drilling of 20 new wells from existing Irong Barat A and a new Irong Barat B platform.
This paper discusses how the integrated field review enabled the team to further develop the field through better understanding of the reservoir and geology and better managing of the uncertainties.
Reservoir Saturation Monitoring in the Attaka Field
Authors: Moinard L. , Boehm M. , Turner S. 
Published: December 2007

Abstract
The Attaka oil and gas field has been in production since 1972 and has produced nearly 600 MMBO and 1.3 TCFG.
In order to maintain production, wells are worked over regularly to shut out water production and to open new reservoir intervals. Determining the amount of gas, oil and water before working a well over is essential. Traditional methods using thermal neutron decay do not work for oil because formation waters are relatively fresh and the contrast between oil and water is too small for quantitative analysis.
Carbon/oxygen logging overcomes the low-salinity limitation in all but low-porosity and very shaly sands. It has been carried out routinely in selected intervals in the Attaka field since 1999 and has become an integral part of reservoir monitoring. This paper presents examples from several wells in the Attaka field, where hydrocarbon saturation from carbon/oxygen (C/O) logging was critical to the successful recompletion of the well. In particular, the drilling of the UA-7RD1HZ intermediate radius oil well was dependent upon accurate assessment of the oil leg location and thickness.
UA-7HZ was logged in the Main Deltaic 44-5A reservoir with the Schlumberger RST tool (combined thermal neutron and C/O log) in March 2000. The resulting log clearly showed an oil leg with enough remaining volume to warrant drilling an intermediate radius horizontal oil well. That well was successfully drilled later in March and has produced enough oil to date to pay out the re-drill. Decline curve analysis indicates that the total volume of oil to be recovered will be nearly 100 MBO. Because this reservoir was scheduled for gas-cap blow-down, this 100 MBO would not have been produced without accurate measurement of the remaining oil leg.
Study of the Mechanism of Polymer Solution With Visco-Elastic Behavior Increasing Microscopic Oil Displacement Efficiency and the Forming of Steady "Oil Thread" Flow Channels
Authors: Wang Demin , Xia Huifen , Liu Zhongchun , Yang Qingyan 
Published: December 2007

Abstract
In this paper, the visco-elastic characteristics of polyacrylamide solution have been studied experimentally. The mechanisms of the effect of polymer solution with visco-elastic characteristic on each type of residual oil after water flooding are analyzed and the mechanisms of polymer solution with visco-elastic characteristic increasing microscopic oil displacement efficiency are studied. By the analysis of microscopic experiments of percolating flow, corresponding relationships between the characteristic parameter describing the visco-elastic behavior of polymer solution and displacement efficiency of residual oil in "dead ends" are given. It is shown that the larger the visco-elastic behavior of polymer solution, the higher the displacement efficiency of residual oil in "dead ends".
A phenomenon that is not seen during water flooding is observed during polyacrylamide solution flooding in the microscopic experiment of percolating flow, that is, residual oil can be pulled into "oil threads" by the polyacrylamide solution. So a new type of oil flow channel, i.e. "oil thread" channel, can be formed and residual oil flows downstream through the "oil thread" channel. The probability of forming a steady "oil thread" flow channel in polymer flooding is also analyzed theoretically and proved.
The research indicates that the mechanism of polymer solution microscopically increasing oil recovery is due to the visco-elastic characteristic of the polymer solution, the sweeping force acting on the residual oil for the visco-elastic polymer solution is larger than that of water. The residual oil is not pushed out by the polymer solution but pulled out by the polymer solution. It is also found that every type of residual oil after water flooding can be decreased by visco-elastic polymer solution, and the larger the visco-elastic property, the stronger the capability of the polymer solution to "sweep out" the residual oil.
In brief, the results indicate that polymer flooding can not only macroscopically increase the sweep efficiency but also microscopically increase the oil displacement efficiency and a new type of flow channel, "oil thread", can also be formed.Besides new understanding on the mechanism of the flow of fluid through porous media and the displacement of residual oil, the above results should be beneficial to designing new EOR methods to further increase the recovery of oil fields.
Multi-Lateral Well Modelling to Optimise Well Design and Cost
Authors: Lee S. S. , Veeken C. A. M. , Frens Ante M. 
Published: December 2007

Abstract
In prolific gas reservoirs with strong aquifer drive, water coning is often the determining factor in well productivity and ultimately, gas recovery factor. One of the main drivers in optimising the field development in these cases is to reduce the drawdown of the wells and consequently, a horizontal well design is often used. It is the case, however, that in such highly permeable gas fields extending the horizontal length beyond 1000-2000 ft often does not help to improve well productivity any further, as well bore friction becomes the constraining factor. This paper presents a cost effective and simple solution to increase well productivity by 60% compared to single horizontals at a marginal cost increase. A simple level-1 dual lateral with large bore casing-flow well design has shown to be able to deliver the additional productivity at only a 5-10% incremental increase in cost. Furthermore, we present the results of the numerical simulation that helped to justify the well design and to deal with interference between the branches.
Development of a Marginal Gas-Condensate Field Using a Novel Integrated Reservoir and Production Management Approach
Authors: Nygård Ole , Kramer Colin , Kulkarni Raghavendra , Nordtvedt Jan-Erik 
Published: December 2007

Abstract
This paper outlines how data acquisition, data analysis, and control actions, can be implemented remotely and in real time to enhance the reservoir and production management process. System components, their integration, and the opportunity they offer to implement reservoir and production management work processes based on real-time data will be discussed and exemplified. We will show how such a system can be implemented on a field. For this, we will utilize the planned installation of such a system in the Huldra gas/condensate field in the Norwegian sector of the North Sea. We will describe how "closed-loop control" for reservoir and production management will be implemented on this field, and give examples from work processes on real-time data leading to faster and better decision support, and, finally, decision making and implementation.
"Pozoteca" Integrated Management of Technical Information on Exploration and Production Wells
Authors: Durán C. F. , Viracachá C. O. , Bejarano A. , Blanco F. A. , Tapias O. 
Published: December 2007

Abstract
The imminent necessity of reactivation of the exploration activities and evaluation of geologic prospects potentially producing hydrocarbons in Colombia, depends on several factors, among those it is counted the most valuable and important, the readiness of information that guarantees an integral knowledge of the areas of interest.
Keeping in mind the existence of computer tools such as the web of the information (WWW) and technological advances in integration, analysis, processing and data administration, ECOPETROL (Oil Colombian Company), and their enclosed Vice-presidency of Exploration, have joined efforts in the process of integration of complete information of wells coming from diverse sources. Furthermore they used brand new technologies in areas of document preservation, storage, organization, structuring, consults and data analysis.
This document shows the change and benefits of a traditional system of location and recovery of information of wells vs. an integrated system of handling wells information via electronic Intranet/Extranet/Internet. The user can consult his area of interest starting from reliable well coordinates, to gather partial or total well logs information, by zones or all depth, to locate the available seismic information, besides the geologic and operative information gathered in drilling processes, logs services, completion and wells production tests.
Additionally the modules, that conform the only POZOTECA of the country, are presented with their structure and the processes of documents capture: vectorizing and digitizing, unification of parameters of acquisition and processing, strategies of databases integration and navigation systems and consults of this valuable key information for the development of the country. This outline according to international experts’ concepts is an unique model that has not been developed in another country of the world reason why it will be very useful for the implementation of similar processes in the national and international oil industry, highlighting that it is a work developed basically with the contribution of the knowledge of national technological base companies.
The philosophy of acquisition, updating, administration, consults and handling of the POZOTECA establishes applicable work protocols to other areas of the knowledge in the oil industry. It guarantees the resources optimization; decrease of costs and it avoids misinformation. Equally, the system increases the productivity of the E&P workers and the discovery of new reserves and business opportunities. The economic and technological contribution of the present project is invaluable and it can be used immediately.
The system is available for data mining and data analysis1,2 processes. It is established architecture for data transformation with features clearly defined e.g. data type, unity and semantic aspects into the E&P environment.
Novel Method for Monitoring and Controlling Asphaltene Deposition in Crude Oil
Authors: Means M. 
Published: December 2007

Abstract
Baker Petrolite has developed a new proprietary method of detecting the asphaltene content of crude oil. The method employs a spectroscopic probe detection technique that measures the amount of dissolved asphaltenes in the crude directly without sample preparation. The device is suitable for both discrete or continuous in-process sample measurements. Laboratory and field test data are presented. The new technique compares with traditional methods of asphaltene characterization including IP-143 extraction gravimetric analysis and ADT spectroscopic methods. This technique, combined with asphaltene inhibitor/dispersant injection control, provides a novel method for the control of asphaltene deposition in crude oil production systems.
The Three R's of Oil Production for the 21st Century
Authors: Lampe S. W. , Veale T. M. 
Published: December 2007

Abstract
For an industry steeped in tradition and energized by innovation, this might be both the best of times and the worst of times to be an oil producer. At the same moment that California is engaged in a high profile energy crisis, the dawning of the 21st century marks a transformational period for oil production.
Producers are undergoing the ultimate challenge — finding technology solutions that will carry forward the promise of what we call the three R's of oil production: reducing O&M costs, demonstrating higher operating reliability compared to existing technologies; and effectively revolutionizing the approach to prime power production.
With less control of operational costs than ever before, how will producers control energy costs, gain free fuel and clean power while ensuring long-term business viability and profit?
In a word: microturbines.
For producers of oil production, microturbines represent a technology breakthrough and "green" opportunity for the producers’ bottom line.
The commercial introduction of microturbines by Capstone Turbine Corporation late in 1998 sparked a new generation of enabling innovation. Two companies are now vying for global market share: Capstone and Honeywell Power Systems.
Capstone emerged as the technology leader in development and commercialization of ultra-low-emission microturbine power systems that are particularly well suited for oilfield needs.
Combining miniaturized jet engine technology with digital power electronics, the simple design of a microturbine belies the fact it solves a variety of onsite power generation needs while simultaneously improving energy economics. Capstone's air-cooled design and patented air bearing technology eliminates the need for any liquid subsystems while mitigating the high maintenance costs and downtime associated with reciprocating engine generator sets.
Effect Of Grid Size In The Compositional Simulation Of CO2 Injection
Authors: Camy J.P. , Emanuel A.S. 
Published: December 2007

Introduction
Numerical dispersion is a well known problem which can cause serious difficulties problem which can cause serious difficulties in simulating the movement of a sharp saturation front. In compositional simulation, the problem is increased by the dispersion of composition fronts as well as saturation fronts.
Several authors have discussed dispersion effects in misable simulation studies.
Nolen noted serious dispersion effects in a compositional study of miscible displacement and used a method of characteristics approach to improve front tracking. Fussell et al. noted a requirement of 100 cells in a cell-to-cell flash model. Todd discussed the use of mixing coefficients and pseudo relative permeability curves to reduce dispersion effects in a 3 or 4 component simulator.
The investigation reported in this paper describes techniques for deriving paper describes techniques for deriving pseudo-functions for reducing dispersion pseudo-functions for reducing dispersion and mixing errors in a multicomponent finite difference compositional simulator. Our technique is aimed at deriving pseudo functions from small fine grid models for use in large scale coarse grid models. The pseudo functions bring the accuracy of the fine grid into the coarse grid calculations. The economics of simulating compositional effects in reservoir simulation will thus look more attractive. In this respect, our approach is similar to that of Cook. Our approach differs from Cook in that the pseudo functions correct a broader range of pseudo functions correct a broader range of numerical problems and are intended for compositional rather than black oil simulation.
Our particular concern is for CO2 injection into reservoir oil, but we believe the pseudo function concepts can be extended to most gas injection problems.

THE GRID SIZE PROBLEM
Among the many parameters that control dispersion and mixing problems, cell size is one of the most important. It is usually recognized that the smaller the grid size, the smaller the dispersion and mixing error. The three most important reasons in a compositional simulator for model results to vary with cell size are:Numerical DispersionNonlinearity of the flash equationNonlinear dependence of saturation and total mobility

Numerical Dispersion
The causes and effects of numerical dispersion in finite difference simulation have been discussed extensively in the literature. In a compositional finite difference simulator, dispersion affects both saturation and composition. The problem becomes further complicated in a problem becomes further complicated in a WAG operation where water and gas are injected alternatingly. If the injected slugs are small, a fine grid will be needed in order to define each slug by at least one or two grid blocks. If slugs are small and the grid coarse, several slugs will be mixed in few cells, as though water and gas had been injected simultaneously. A WAG displacement process cannot then be adequately represented.
The Demand for Natural Resources Revisited
Authors: Vogely William A. , Bonczar Elizabeth Semon 
Published: December 2007

Abstract
Two models for explaining the demand for natural resources are developed for the period 1900–1969. The first model relates demands for total natural resources and five sub-categories to the size of the economy, real prices, and the state of technology. The second model relates the intensity of use of resource categories and sub-categories to real prices and technology. The major findings are that the United States has been using raw materials more efficiently through time during this century and that the current state of the data base is not sufficient to choose between alternative hypotheses of the determinants of intensity of use. Directions of future work are indicated.

PART 1 PART 1 OVERVIEW
The subject of raw material demands with respect to economic growth has become an increasingly important one, especially in the area of energy. In 1974 in a paper presented before the Council of Economics, Dr. Malenbaum proposed a law of demand for minerals, including proposed a law of demand for minerals, including fuels. His thesis was that the intensity of use of a mineral; i.e., consumption of the mineral per unit of gross national product (GNP), is a function of GNP per capita. Further, he stated that the shape of this function was an inverted "U"; that is, as per capita GNP increased, consumption per unit of output for a mineral would increase, reach a maximum, and then decline. The data lying behind the Malenbaum hypothesis related to specific mineral commodities, such as copper or iron and steel, and his reported data covered a short span of time. In an earlier article, I (the senior author) explored the Malenbaum hypothesis. I concluded that a metal by metal analysis of intensity of use through time is most likely picking up substitution phenomena rather than fundamental tendencies phenomena rather than fundamental tendencies in the demand for total raw materials. This is illustrated clearly when one puts in juxtaposition the trends for aluminum and copper, and combines them in terms of relative weights. Further, the shift from goods to services is not necessarily a raw material saving shift. Thus, changes in the composition of GNP as per capita income rises may not be an adequate explanation for the inverted "U" posited by Malenbaum. I concluded my posited by Malenbaum. I concluded my examination of Malenbaum as follows:
" My preliminary work leads me to believe that the major phenomena that must be understood are the process of substitution and the relationship of materials demands to technological progress.
The Effect of Stimulation Methodologies on Production in the Jonah Field
Authors: Eberhard Mike , Mullen Mike 
Published: December 2007

Abstract
Improvements in stimulation technology have continued to increase our ability to economically extract hydrocarbons from very low permeability reservoirs. The Jonah field, in Southwest Wyoming is a classic example of a reservoir that was commercialized with newer stimulation technology. The Lance formation in the Jonah field consists of several hundred feet of stacked lenticular sands with reservoir permeability to gas less than 10 µD. Completion techniques have evolved over the years employing a variety of hydraulic fracturing techniques. In the past 2 years three techniques have emerged as the predominant completion methods: traditional nitrogen assist, induced stress diversion, and the use of flow thorough composite bridge plugs. This study evaluates the different techniques using spatial sampling to compare each well to its offsets and identify the completion scheme that yields the best results on cumulative production. From this study a clear best practice for completing wells in the Jonah field to maximize production was determined.
Conditioning Integrated Geological Models to Dynamic Flow Data of Giant Saudi Arabian Reservoir
Authors: Al Qassab Hisham M. , Rahmeh Basem A. , Al Khalifa Mohammed A. , Awami Bassam , Sarkar Amit 
Published: December 2007

Abstract
A fine-scale full-field multimillion cell geologic model of a giant Saudi Arabian carbonate reservoir has been successfully conditioned to a thirty-year production/injection history. This represents the first worldwide case study of the technique for such a complicated reservoir with extensive flow history.
The initial geologic model was created based on log-derived porosity data, facies information, and a 3-d stochastic seismic inversion model. It was generated geostatistically using a sequential Gaussian simulation with collocated cokriging algorithm. It was desired to condition this initial model based on a thirty-year injection/production history.
Fast streamline simulations were performed on the geological porosity and permeability models using field injection/production constraints. The flow conditioning algorithm iteratively modified the permeability field such that simulated injection/production behavior more closely approached the supplied injection/production history. The algorithm uses analogies to seismic travel time and tomography, involving iterative linearization of the time-of-flight expression about a known initial model based on static data.
The final flow conditioned model was then validated using more thorough streamline simulations verifying improvements in the match of the simulated injection/production response to that of the historical response. Additionally, inspection of the difference between the initial and the flow-conditioned final model showed permeability modifications followed a strong directional trend consistent with well-known geological trends. Results from the final conditioned models showed more than 30% improvement in terms of history-matching than that of initial model.