bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Application of Kohonen Type Self Organization Algorithm to Formation Evaluation
Authors: Chawathé Adwait 
Published: December 2007

Abstract
Reliable and comprehensive well log data is essential for a reasonable evaluation of the underground rock formations and the in-situ hydrocarbons. This log data has to be interpreted with good statistical confidence to predict the performance of a well. In order to automate the process of log interpretation and hence potentially reduce its cost, a Neural Network (NN) can be trained for interpreting logs with reasonable accuracy. This paper discusses the possibility of applying the Simulated Neural Network (SNN) technology to the art and science of well log interpretation.
The algorithm used to generate the SNN used the Kohonen unsupervised learning technique. Basic principles of the SNN thus created have been considered and the results obtained from the training and SNN log interpretation have been discussed.
Technology Transfer Around the Corner?
Authors: Willis R. B. , Rowell Deborah , Patchen Douglas 
Published: December 2007

ABSTRACT
This paper will describe how the Oil and Gas industry can become involved in shaping a new national program to aid in the transfer of technology from a variety of sources to the hands of the local independents.
Technology Transfer has been a "buzzword" in the Oil & Gas Industry for some time now. Most of us might admit that it has been more of a "buzzword" and less of an activity than we would like. While most of the operators in the Appalachian Basin want to apply the latest in technology to their exploration and production activities is has quite often been difficult to find the appropriate technology. The Department of Energy, realizing that much of the technology which exists involving Oil and Gas is seldom applied by those who work so hard to produce it efficiently, has instigated the Petroleum Technology Transfer Council (PTTC). The PTTC will be a national "umbrella" organization formed by the Independent Petroleum Association of America (IPAA), in cooperation with the state and regional oil and gas producer associations, the Gas Research Institute (GRI), the Interstate Oil and Gas Compact Commission (IOGGCC), and other groups. The mission of the PTTC is to foster the effective transfer of exploration and production technology to domestic producers in all regions of the country. One of the most important functions of the program will be to provide a feedback loop so that the needs and concerns of producers can be communicated effectively to the entire research community and to the Department of Energy.
The PTTC program has three main components: Problem Identification WorkshopsFocused Technology WorkshopsRegional Resource Centers
The PTTC has the potential to aid producers in the Appalachian Basin if they understand the program and become involved in directing it to serve their needs. 1994 will be the formative year, ultimately deciding its acceptance by regional producers.
Cost and Resolution in 3D Surveys for Stratigraphic Traps
Authors: McDonald J. A. , Tyler N. , Uren N. F. 
Published: December 2007

ABSTRACT
The three-dimensional seismic method is now widely recognized as a very valuable tool for characterizing reservoirs. We show that an understanding of the tool's resolution capabilities can be readily made in the laboratory using models. Channelized reservoir systems such as fluvial deposits can be characterized by the careful use of the three-dimensional methods, VSP and bottom-hole pressures and an example is given from a mature field in Texas.
Applications of Risk Analysis in Petroleum Exploration and Production Operations
Authors: Moore Kevin S. , Cockcroft Peter J. , Prasser Ross 
Published: December 2007

Abstract
Risk analysis is a method of quantifying the effects of uncertainty on decision outcomes. In many E&P decision analyses, evaluators do not explicitly consider the uncertainties and possible decision outcomes but instead present only a single, most likely result. Often the uncertainties are considered subliminally. This practice can lead to sub-optimal decisions.
Explicit forms of risk analysis can improve decisions by providing more accurate representations of possible outcomes. This paper will illustrate decision and risk analysis techniques applied to several technical decisions in E&P operations. Although uncertainties exist in many different areas – technical, environmental, political, corporate, – only those in technical project evaluations will be discussed.
Application of Resistivity Inversion Software to Thin-Bed Evaluation
Authors: Warrilow I. M. , Ibrahim Rusidah , Chin Ho Tiong , Forsyth D. 
Published: December 2007

ABSTRACT
In a seemingly ever growing number of fields, the petrophysicist is being confronted by the challenge of evaluating thinly bedded formation sequences (i.e. beds whose thickness is below the resolution of most of the contractor "standard" open hole logging tools). The evaluation of such beds is indeed a challenge as more often than not the available wireline data does not provide anywhere near sufficient resolution to enable a proper evaluation of such beds. At best, the interval may be cored and indications of hydrocarbons detected. At worst, the interval could be totally over-looked due to misinterpretation and business opportunities missed.
To assist the interpretation of such zones the mathematical technique of "inversion" has been applied to the resistivity suite of logs. Through the use of "inversion" or "resolution enhancement" software the apparent resistivities (derived directly from the resistivity tool) are automatically corrected for such environmental effects as shoulder-bed (bed boundary) effect, saline-borehole fluids and invasion. This results in "true" formation resistivity values being obtained on a layer by layer basis. The technique is not restricted to the more recent logging tools but is also applicable to the older resistivity tools (normal and lateral devices).
This paper will demonstrate, through a number of field examples, how the inversion technique can be applied to substantially improve our current understanding of "true" formation resistivity and thus our "conventional" petrophysical evaluation.
Effects of Polymer Concentrations, Slug Size And Permeability Stratification in Viscous Waterfloods
Authors: Wang G.C. , Caudle B.H. 
Published: December 2007

Abstract
A streamline type mathematical model has been developed which may be used to study oil recovery by viscous waterfloods for any desired well spacing. The model was used to study the combined effects of permeability stratification, polymer concentration and viscous water slug size for a five spot injection pattern.
Five different permeability profiles ranging from a homogeneous to a highly stratified reservoir were studied. It was found that viscous water floods show greater percentage increase (over conventional water percentage increase (over conventional water floods) in oil recovery for stratified reservoirs than for homogeneous reservoirs. A highly stratified reservoir containing viscous oil showed a 96% increase in recovery for a particular viscous water flood. it was also found that the adverse effect o connate water on oil recovery becomes insignificant as the degree of permeability stratification approaches a large number.
Guide-lines for the determination of an optimum slug size and viscosity were derived. Generally speaking, it is advisable to use a high viscosity, small size slug in flooding a homogeneous formation, while stratified reservoirs do better with the use of a large diluted slug. It was found that there exists an optimum slug size for a given amount of thickening chemical depending upon the oil viscosity and degree of permeability stratification. The increase in oil recovery by selecting an optimum slug size may be sizeable in some instances.
Introduction
The role of mobility ratio in water flooding has been well established. Thickening of the injected water or otherwise increasing its resistance to flow brings about this improvement through a decrease in its fluid mobility. Early attempts to decrease the mobility of the injected water were uneconomic, but, during the past few years, the use of a high molecular weight water-soluable polymer has shown promise as an effective polymer has shown promise as an effective material in reducing the water mobility. Results from both laboratory and field pilot tests indicate that the concentrations of polymer required in the injection water to polymer required in the injection water to effect substantial increase in flooding efficiency are usually low enough to satisfy normal profitability criteria.
Much has been written postulating the mechanisms by which the mobility of water is reduced by the addition of a polymer.
Optimized Exploration Resource Evaluation Using the MDT Tool
Authors: Zainun K. , Trice M. L. 
Published: December 2007

ABSTRACT
This paper discusses exploration cost reduction and improved resource delineation benefits that were realized by use of the MDT* (Modular Formation Dynamic Tester) tool to evaluate exploration prospects in the Malay Basin of the South China Sea. Frequently, open hole logs do not clearly define fluid content due to low salinity of the connate water and the effect of shale laminae or bioturbation in the silty, shaly sandstones. Therefore, extensive pressure measurements and fluid sampling are required to define fluid type and contacts. This paper briefly describes the features of the MDT* tool which were utilized to reduce rig time usage while providing more representative fluid samples and illustrates usage of these features with field examples. The tool has been used on several exploration wells and a comparison of MDT* pressures and samples to results obtained with earlier vintage tools and production tests is also discussed.
Determination of Petrophysical Parameters Using Wireline Logs in Low Salinity Reservoirs
Authors: Goode Peter A. , Pietsch Andrew P. , Williams Neil V. , Sibbit Alan M. 
Published: December 2007

Abstract
This study defines an approach to determine porosity, fluid saturations and permeabilities from wireline log data in sandstone reservoirs containing low salinity formation brines. An extensive set of measurements were made on low invasion core were analyzed to establish the ground truth, and to control the input parameter choices for log analysis.
A recently developed water saturation equation, that accounts for the different geometry of the conducting paths along grain surfaces and within the pore fluid, was used to analyze the wireline resistivity logs. This equation predicts far less resistivity contrast between hydrocarbon and water-bearing intervals than other widely used relationships.
The log interpretation technique consists of making robust estimates of highly sensitive parameters such as the cation exchange molarity, Qv, and paying attention to the details in the estimation of the true formation resistivity, Rt and the formation resistivity factor, F.
Application of Reservoir Management and Reservoir Simulation to Monitor and Improve the Performance of the M4/7/N1 Reservoirs in the Samarang Field, Offshore Sabah, East Malaysia
Authors: Baxendale David 
Published: December 2007

Abstract
The Samarang field was discovered in 1972, offshore south west Sabah, East Malaysia. The field was declared commercial in 1974, and first production commenced in 1975. The M4/7/N1 cluster of reservoirs is one of the main groups of reservoirs in the Samarang field, containing some 23% of the field's expected ultimate recovery. The observed basal/edge natural water drive and the gascap expansion drive are expected to recover about 50% of the M4/7/N1's original oil in-place. However, the combined drive was not anticipated to fully sweep the reservoir. Hence, the need for a field wide review of the reservoir.
To actively manage the remaining hydrocarbon resource a detailed 3D full field simulation project was initiated. A comprehensive geological study of the M4/7/N1 reservoirs was first conducted to formulate the geological input to the simulation model. The model was validated by history matching the reservoir's seventeen years of production data, This model was then used to actively manage the hydrocarbon resource base by: predicting future oil recovery under various development options, locating potential infill well locations, and by optimising the reservoir management strategy.
Reservoir management of this mature field through the utilisation of reservoir simulation tools, has helped to maximise hydrocarbon recovery by determining the optimum depletion strategy with respect to the remaining hydrocarbon resource. Future infill drilling locations have been identified and the results from the model have been used to support the operator's development strategy for the pool.
Review Of Early Horizontal Well Applications In Central Sumatra
Authors: Arnold C.W. , Djauhari H.H. 
Published: December 2007

C.W. Arnold* and H. H. Djauhari*

Abstract
This paper reviews the first applications of horizontal wells in the Caltex Pacific Indonesia (CPI) area of operation in Central Sumatra, Indonesia. Drilled in late 1993 and early 1994, these wells now provide enough history for an initial evaluation of the results. These results are encouraging and CPI is reviewing further applications of this technology, which is viewed as another technique for squeezing more oil out of mature fields. The project histories, ranging from concept to evaluation, drilling, and actual performance results, are briefly covered. Emphasis is placed on the evaluation methodology, involving a blend of analytical and simulation methods, and comparison of performance predictions with actual results.

Introduction
CPI's area of operation is characterized by numerous mature fields with significant reserves, permeability, aquifer influx, and multiple stacked sandstone reservoirs. High producing water cuts and water coning are significant problems. Both the Minas and Petani fields used horizontal wells to target thick bottomwater sands which cone significantly in vertical wells. In Minas, the objective was to reduce water cut and capture bypassed oil from a fining upward section. In Petani, the concept was to reduce coning, increase rates, and improve well management by allowing the recompletion of existing vertical wells upward into unopened pay.
The evaluations included a review of the geology and performance predictions designed to address the complications in each field. These include the very high permeabilities and fining upward sequence in Minas and the influence of neighboring wells in Petani. Generally, the results have been good and these projects offer useful case histories of horizontal well applications.

Background
Both the Minas and Petani fields are located in the Pertamina-CPI Production Sharing Contract Area in Central Sumatra, Indonesia (Fig. 1). The Minas field is the largest in Southeast Asia with an estimated original-oil-in-place (OOIP) of nine billion barrels. The Petani field, although smaller, is still sizeable with an estimated OOIP of about 690 million barrels. Petani is located 12 miles west of the Duri field, site of a large steamflood operation. Significant oil reserves remain in both fields and methods of efficiently recovering that oil are of strategic interest to the company.
P. 337
Centrifugal Wellstream Separation of Water and Sand
Authors: Christiansen Bjørn , Kvamsdal Dag , Dannström Henrik 
Published: December 2007

Abstract
This paper discusses problems and technical solutions in developing a non-rotating centrifugal separation system to remove water and sand from the well fluid prior to choking and multiphase transport from a satellite field.
The paper focuses on the usefulness of CFD-tools for hydraulic design of the primary oil/water separator. Furthermore, the experimental investigation of the gas/liquid separator and the primary oil/water separator are described in terms of scope, test rig setup and preliminary results. Finally, other applications utilising parts of the project core technology, are briefly outlined.
Incorporation of Production Data in a Reservoir Description Process
Authors: Oetomo Hari K. , Kelkar Mohan G. 
Published: December 2007

ABSTRACT
In this study, we propose a technique to include production data as a part of the constraint in a reservoir description process. Based on the simulation studies, we observed that, during secondary recovery performance, the production parameters such as water breakthrough are closely tied to the connectivity between injectors and producers. Using this relationship, we introduce a method which allows incorporation of production data as a part of the constraint through an equivalent static parameter. For the purpose of incorporating this information, we use the method of simulated annealing.
Using this connectivity function along with the near-well permeability, we show that the uncertainty in the reservoir description is significantly reduced. We validate our results by conducting the reservoir simulation for a full field scale simulation based on the Burbank Field in Oklahoma. These results clearly indicate the need for the incorporation of production data in generating the reservoir description.
Gas Fields Development in Malaysia
Authors: Seong Chen Kah , Husain Darwis , Karim Abdul Hamid Abdul 
Published: December 2007

ABSTRACT
This paper is a review of the gas fields development in Malaysia. The major subsurface engineering considerations for gas development include drive mechanism determination, well requirement, completion strategies, well deliverabilities, recovery factor and reservoir surveillance requirements. For surface engineering, the major considerations include offshore facilities function, platform configuration and sequence and process and compression requirements. The result of the review is the summary of some of the differences in gas fields development to date.
Concrete Platforms for Southeast Asia
Authors: Hoff G. C. , Reusswig G. H. 
Published: December 2007

ABSTRACT
The use of concrete offshore structures for hydrocarbon resource developments in SE Asia has, to-date, had little precedent but their potential across the region seems unlimited. The interest is continuing to grow because the structures can be built using local materials and local labor in the countries where the platforms are to be used. For many applications, they are cost competitive with steel structures. The concrete substructure requires little or no maintenance throughout the life of the structure, thus reducing operating costs. The concrete structures can be self-installing without the use of crane barges or heavy-lift vessels. They are re-floatable and can be used again in other locations. They also can be designed to include oil or condensate storage within the structure, thus eliminating the need for additional floating storage in areas where offshore pipelines do not exist. The paper describes a few concrete structure concepts that are applicable for Indonesia, Malaysia, Vietnam and Australia and considerations for their use.
Development and Verification of Flexible Pipes for Deepwater Applications
Authors: Makino Yoshiyuki , Kagoura Toru , Ishii Kenichi , Fuku Tadashi , Kawakama E. H. , Yamaguchi Takumi 
Published: December 2007

ABSTRACT
In 1993, Furukawa Electric delivered flexible pipes to PETROBRAS for use in deep offshore oil field at 500 m of water depth. This paper presents flexible pipe design points, development item, type approval and verification for deepwater applications.
IADC's Well Control Accreditation Program (Well Cap)
Authors: Kropla S. M. 
Published: December 2007

ABSTRACT
In early 1995, the International Association of Drilling Contractors will implement its Well Control Accreditation Program, known as WellCAP, throughout most parts of the world. WellCAP marks the first attempt by the drilling industry to put in place a comprehensive system to define a core well control training curriculum, establish minimum standards and recommended guidelines for course structure, and provide a means of formally recognizing schools which meet the association's accreditation criteria. Originally intended primarily for use in emerging and undeveloped areas, the program has since been proposed as an alternate method of approving well control schools in the U.S.
Analysis of Drillstring Failures
Authors: Reid David , Rabia Hussain 
Published: December 2007

Abstract
The drilling industry is currently exploring various ways of reducing drilling costs through a multitude of initiatives; for example C.R.I.N.E. (Cost Reduction In the New Era). One of the major areas where there is potential for cost reduction is downtime due to hole problems and drillstring failures.
Over the last five; years, British Gas (B.G.) has experienced a number of drillstring failures despite following the industry accepted practices of drillstring design. As a result of this, a substantial research programme was initiated to investigate the fundamental mechanics of drilling vibrations, and in particular the prediction of the onset of a resonance that contributes to a fatigue failure. The programme concentrated on four major areas: A full metallurgical analysis of the failed components;Development of mathematical models to predict natural frequencies;A collection of field data; andBuilding a laboratory based scale model drillstring rig to generate vibration data and validate the mathematical models in conjunction with field data.
This paper presents details of the above research programme that results in a substantial reduction of drillstring failures. It will present field examples from both onshore and offshore wells. The paper also details British Gas's approach to the reduction of harmful resonance through the strategic placement of a shock sub.