bluuebunny/crossref_metadata_2025_split huggingface dataset:
Producing Interactive Environmental Impact Assessments on CD-ROM
Authors: Rabin Karen M. 
Published: December 2007

Abstract
Environmental Impact Assessments (EIAs) can be lengthy, complex documents. A typical EIA might contain 250 pages of text, 10-20 color figures, 30-40 tables, and 5-10 lengthy appendixes. These documents quickly become cumbersome for the reader. In addition, pages may easily be lost or damaged. Printing and binding costs for complex EIAs are expensive (hundreds of dollars per copy), and often limit distribution.
To help solve these problems, Walsh Environmental Scientists and Engineers Inc. (WALSH) produces large EIA documents in hypertext markup language (HTML) on a CD-ROM for easy viewing and distribution. The final product contains the entire document, tables, figures, appendices, and laboratory analytical data. Internal links allow the reader to access a figure or table from the place it is mentioned in the text, in the same way one navigates a web page. A linked table of contents enables the user to click on any section, table, or figure and jump to that position.
Reproduction of CD-ROMs is inexpensive (about $25 per copy) and fast, so the EIA can be widely distributed. In addition, data on CD-ROM are virtually indestructible and cannot be altered. Physical storage requirements for CDs are less than for the 4" binders used for printed copies. Another benefit is that once an EIA has been produced in HTML format on CD-ROM, it can be easily transferred to a web server and accessed by people anywhere in the world through the Internet. If desired, password access can protect confidential information.
Transforming Environmentally-Impacted Sites into Optimum Returns
Authors: Daddario David J. 
Published: December 2007

Abstract
Oil and gas companies are looking for new ways to raise cash and remain competitive. However, outmoded or underutilized facilities with environmental problems, such as hydrocarbon-impacted sites, can be a major financial drain. Plus, the public outcry about pollution can be difficult to manage. This session will review the new property divestment strategies that companies are utilizing to reduce liability, foster community support, optimize financial returns, and create economic development.
From a financial and legal perspective, new tools have become available over the last six months to cap costs and raise cash from problem real estate. Understanding the marketing potential of a problem site and identifying reuse opportunities are key to a cost-controlled cleanup effort and creation of a new product in the marketplace.
Using case studies, this session will describe how applying new strategies and tools can help to: –Minimize cleanup costs,–Maintain community support,–Negotiate strategies with regulators, and–Create optimum dollar return and economic development.
Cyclic-Steam Injection Initiation Project in Heavy Oil Reservoir – A Simulation Study
Authors: Rajtar J. M. , Hazlett W. G. 
Published: December 2007

Abstract
In this paper, a short pilot simulation study of new heavy oil cyclic steam injection project in California is presented. The new project is located in the proximity of the current cyclic steam project, which was used as reference for key reservoir data. The heavy oil reservoir is initially at low temperatures. For this reservoir, a number of project inititiation scenarios are evaluated on the basis of cumulative oil production. Scenarios involve evaluation of the number and location of horizontal and vertical wells for the most effective steam placement and oil recovery.
In the first part of the study, ten scenarios are compared for a simple assumed model of the area under consideration. From these, the three most interesting scenarios were selected for further study. In the second part of work, the reservoir model was adjusted to reproduce average observed field rates per well. After this simplified history match, three selected cases were rerun and the fourth case was added. Details and description of the simulated scenarios are presented in the paper. Scenarios are compared on the basis of cumulative oil production. Results indicate strong dependence of the cumulative oil production on the well location with reference to the Water Oil Contact (WOC). Effects of injection rate, and well and injection timing are also illustrated. All the presented strategies result in an increase in cumulative production.
Production Performance Simulation of a Horizontal Well in the Bolivar Coastal Fields, Zulia State, Venezuela
Authors: Perez Carlos A. , Salazar Victor M. , Elias Lopez 
Published: December 2007

Abstract
The objective of the present project is to develop a simulation model for one of the thermal projects of the Bolivar Coastal fields in the Zulia State, Venezuela. For this purpose, a thermal simulator was used in order to model the oil production performance from a 1640 Ft. horizontal well, and also, from infill wells located in the line of the horizontal well. With these results, to evaluate and compare the profitability of both production performances and to optimize the future operation strategy, continuing with the cyclic steam injection (C.S.I.) process.
Taking into account the geological model, recently developed for the thermal project, as a result of an integrated reservoi study, the production performance simulation of the horizontal well was accomplished in the most convenient area, where there are ten oil production wells in operation.
A three-dimensional and multiphase thermal simulator was used. A Cartesian grid of 9x23x12 blocks, representing the 3 objectives (4 layers for each one) was created. Once th history matching was successfully done (for each one of the ten wells), five prediction cases were chosen among different developed cases. The horizontal well was included in three of these cases, with the purpose of determining oil potential. A economical analysis was applied in order to recommend the most profitable case and plan the future exploitation scheme for the area.
It was also recommended to apply the present evaluation methodology to other areas of the cyclic steam injection projects in the Bolivar Coastal fields to identify areas as future steam drive candidates.
Management of Water Alternating Gas (WAG) Injection Projects
Authors: Sanchez Néstor L. 
Published: December 2007

Abstract
This paper summarizes the results of several successful WAG projects presented in many Improved Oil Recovery (IOR) Symposiums, indicating the main technical and operational issues considered in the development and implementation of such projects, and the management strategy for monitoring the process (Refs. 1,2,3,4). The results from these field applications will serve as useful guides and examples for improving reserves from many of our mature fields, and would lead to rethinking our strategy of reservoir development and new technology application for significant reserves enhancement in Venezuela. The paper focus on the selection of the technical aspects that must be consider in the implementation and management of the Water Alternating Gas (WAG) Injection process, providing an useable reference for the front line geoscientists, reservoir engineers, production operation engineers and technical managers who wish to obtain a technical and operational overview of the process as applied in the petroleum industry.
Managing W AG injection projects requires making decisions regarding to the WAG ratio, half-cycle-slug size, and ultimate solvent slug size for each WAG injector in the field. The impact of these decisions affects the capital cost of solvent purchase, water and gas plant loads, fluid handling and lifting operation costs, and ultimate incremental oil recovery. Simulation models provide a tool for examining strategies for these decisions. However, it must be able to address operational impacts such as lift method and problems, injecting plugging, workovers and facilities operations. Project monitoring incorporating actual performance data into the reservoir models provides an excellent diagnostic tool for decision making. The technical considerations for managing WAG projects presented in this paper can be used as a methodology for monitoring projects performance at pattern and full field level, increasing understanding of the process performance, and improving decision making.
A New Small-Diameter, High-Performance Reservoir Monitoring Tool
Authors: Simpson G. A. , Jacobson L. A. 
Published: December 2007

Abstract
This paper discusses a new small-diameter, high performance pulsed-neutron spectrometry tool that has been introduced recently for reservoir monitoring applications. Basic measurement principles are explained, and important operating parameters are presented. Field examples from Western Venezuela and South Texas illustrate multiple applications of the new device and compare the performance of the new instrument with a larger pulsed-neutron spectrometry tool.
The new 2-1/8-inch tool is designed for logging through 27/8-inch or larger tubing. The tool is slightly larger than traditional 1-11/16-inch through-tubing tools. This design accommodates larger detectors, thereby improving the performance of the carbon-oxygen (C/O) measurement. Two bismuth germanate detectors yield high gamma ray count rates with good spectral resolution.
To optimize C/O measurements, one mode of tool operation interlaces 5ms of background measurements with 20ms of 10-kHz neutron pulses. The tool records 256-channel spectra from each detector: during the neutron bursts (for analyzing inelastic events),during the interpulse period (for analyzing capture events), andduring the background period (for analyzing activation and background events).
The tool also provides a simultaneous neutron capture cross section (sigma) measurement. Carbon-oxygen and calcium-silicon (Ca/Si) response characteristics for saturation and lithology analysis are derived from laboratory measurements and are illustrated in the customary fan-chart format. In a second mode of operation, the tool optimizes the sigma measurement and provides high-quality neutron capture spectra for quantitative lithology determination.
Use of Oriented Perforation and New Gun System Optimizes Fracturing of High Permeability, Unconsolidated Formations
Authors: Soliman Mohamed , Dupont Richard , Folse Kent , Mason Justin , Burleson John , Azari Mehdi 
Published: December 2007

Abstract
When designing fracture treatments for high permeability formations, fracture conductivity is a primary factor in attaining maximization of completion economics. Optimum fracture design would dictate the knowledge of fracture orientation and the utilization of oriented perforation to optimally place the fracture. While in many unconsolidated formations, the contrast between horizontal stress is small or even insignificant; taking advantage of this situation often improves the efficiency and placement of a fracture.
It is generally believed that existing spiral patterns used in more conventional slurry pack completions give better radial flow performance because of the uniform perforation distribution around the wellbore. However, when a hydraulic fracture is created, the majority of flow into the wellbore is delivered through the perforations that are communicated to the fracture. This is especially true when many of the unconsolidated formations suffer a high degree of damage around the wellbore. For this reason, it is important to focus fluids injected during the completion directly to the fracture and increase the number of perforations communicating with the fracture. This paper will discuss the justification and theoretical background for a newly proposed design that develops this concept. The paper also discusses the tools and procedures necessary to achieve the stated goals.
A case history will be presented that will discuss the methods employed by an operating company in offshore Louisiana in perforating unconsolidated formations with the new system to obtain highly conductive gravel-pack fractures in deviated vertical wells. Significant to the success of the completions was the use of a high shot density perforating gun, oriented at 180-degree phasing. To facilitate the new approach, an innovative perforating gun system was also developed, and a wide perforation was designed to minimize friction.
Case History: New Gas Flow Computer Design Facilitates Offshore Measurement in Gulf Coast Project
Authors: Bonin Wayne , Chunn Mike , McFarland Danny E. , Jenkins Ken , Fink Kevin 
Published: December 2007

Abstract
Electronic gas measurement has evolved from providing a simple replacement for circular chart recorders to requiring instantaneous remote access of flow information. Coupled with this capability is the need to have simultaneous access to this information from multiple locations. Without existing equipment to meet these requirements, a major oil and gas operator and an oilfield equipment engineering and manufacturing company joined forces to develop a new flow computer that would meet the needs of the operator's present communication system and would adapt to future needs. Installation of the new flow computer has significantly enhanced operating efficiency by requiring fewer trips to offshore locations, providing instantaneous flow information for engineers, technicians, and gas accounting personnel, and providing consistency in measurement instrumentation. These advantages have reduced overall operational costs as well as increased personnel training efficiency.
Gas Production Management Options
Authors: Mochizuki Satoshi 
Published: December 2007

Abstract
The primary objective of this study is to extend an oil production plateau period through gas management when the production is limited by the gas handling capacity. Once gas break-through occurs, we would like to know how we should operate to minimize gas production; how effective existing methods are; how we could delay the break-through time. There are a number of options including rate cutback, completion shut-off, well cycling and drilling infills. Effectiveness of those methods may vary depending on reservoir types. This study evaluates relative effectiveness of a number of methods for an existing reservoir using 3 numerical models and field examples.
Evaluation of Exploration Areas using Extension of 3D Techniques in Mature Areas
Authors: Villaroel V. , Garcia E. , Ronny R. 
Published: December 2007

Abstract
The goal of this paper was to evaluate and incorporate new hydrocarbon reserves in exploration areas nearby to highly developed fields, via extrapolation of 3D seismic attribute techniques into a 2D seismic grid. The project evaluated an area of approximately 180 Km2 located to the west of Budare field, using sequence stratigraphy interpretation techniques in about 100 line Km of 2D seismic acquired in 1966, as well as interpretation on aproximately 100 Km2 of 3D seismic gathered in 1994. Petrophysical and reservoir data were analyzed along with the 3D seismic in the field area using computer-integrated systems, to provide the link between the seismic and the field arquitecture. This information was then extrapolated to the 2D seismic grid and allowed to determine the possible direction and geometric extension of sand channels in the exploration area. This interpretation helped to identify several stratigraphic and structural plays in the new area, composed mainly by upper Oligocene - Miocene fluvio deltaics sands of about 200 feet in thickness at a maximum depth of about 4000 feet. Total estimated reserves on this plays is on the order of 30.7 MMB with gravity ranging in the order of 35 API, representing about 30% of the remaining reserves in the Budare field. The incorporation of these plays increased drastically the potential of the area due to the characteristics of the crude and reservoir, along with their closeness to the existing production facilities.
Sequence Stratigraphy and Sedimentological Model of Barúa Field Reservoirs, Eocene Misoa and Paují Formations, Lake Maracaibo, Venezuela
Authors: Escandón G. , Moreno M. , Chacartegui F 
Published: December 2007

Abstract
This paper presents the sedimentological and stratigraphical model for the Eocene section of Barúa Field, Maracaibo Basin, Venezuela (Fig 1). The main reservoir units are comprised at the base by the Upper Misoa sands (B-0/B-1) and at the top by the basal Paují sands (A-9/A-10).
The objective of this study was to establish and predict the geometry, distribution and physical reservoir quality of the flow units in order to implement a viable economic exploitation plan.
Hydrocarbon extraction in the Barúa field began in 1957 after the successful drilling of well MGB-1x. This field is producing 16 MB/D, and has so far reached a cumulative production of 83.3 MMB. The estimated OOIP is 1.4 MMMB and total remaining reserves are in the order of 226.7 MMB.
The Evolution of Horizontal Completion Techniques for the Gulf of Mexico: Where have we been and where are we going?
Authors: Foster Jeff , Grigsby Tommy , LaFontaine Jackie 
Published: December 2007

Abstract
Since the early 1990's, horizontal openhole screen completions have continued to gain acceptance as a viable completion technique for Gulf of Mexico high-permeability, soft-rock completions. The primary drivers for encouraging the use of this type completion have been the higher production rates that, when coupled with the increased percentage of recoverable reserves, have provided a quicker and greater return on investment (ROI) than other completion methods. Advances in directional and horizontal drilling, measurement-while-drilling (MWD), and fluid systems were the enabling technologies for drilling and completing of long openhole horizontal intervals. Because of the horizontal environment, specialized completion systems were required, developed, and successfully deployed. These systems have combined proven technology with new packer and service tool designs, production screens, etc. to adapt to the rigorous demands of the horizontal wellbore.
The viability of this completion technique is now being questioned as a result of the increasing number of completion failures. Some completions have experienced production rate declines, water coning, and/or sand production. Why has this problem suddenly become more pronounced?
This paper will discuss the chronological development of horizontal completion systems and the perceived drivers as well as the current innovations in completion tools and techniques. In addition, the speculation and causes related to horizontal completion failures will be addressed. Finally, the paper will discuss the completion trends of the future and attempt to answer the questions asked in the title by providing some possible resolutions to current horizontal completion problems.
Detection of Channel Sands and Vertical Shale Continuity Using a new Approach in Interference Analysis of Parallel Horizontal Wells
Authors: Alkhonifer J. , Ershaghi I. 
Published: December 2007

Abstract
This paper presents a new form of monitoring pressure interference data between two parallel horizontal wells for mapping reservoir permeability structure. The method is based on integrating the responses at multiple isolated probing points along a horizontal well path, and mapping permeability profiles from the application of a hybrid of deterministic and stochastic models.
Application to realistic system includes complex systems with channel sands embedded within an otherwise low permeability reservoir and discontinuous shale layers affecting vertical permeability.
The proposed method conceptually requires one or more pulsing points within the active horizontal well and a tool similar to an EFT moved along the responding well. Pressure responses from a series of interference tests, between two horizontal wells, are modeled to map the permeability distribution between the two wells.
The procedure has application in designing SAGD and other recovery processes in reservoirs where pairs of horizontal wells are planned for improved recovery. Information obtained, however, can further help in conditioning of geological models for other well configurations.
Layer Modeling for Cuttings Transport in Highly Inclined Wellbores
Authors: Kamp A. M. , Rivero M. 
Published: December 2007

Abstract
A review is presented on the state-of-the-art of mechanistic cuttings transport modeling. Cuttings transport predictions are essential for the planning of directional and horizontal drilling. It is suggested that field requirements (the need for fast, easy to use, simulators) point towards the use of a combination of two distinct modeling strategies, which are layer-models for the flow along the wellbore, and full numerical solutions in given cross-sectional areas. The layer model approach is developed in detail, yielding a two-layer model that simulates a moving bed of packed cuttings below a heterogeneous layer of mud and cuttings. Some key points on which more research is needed are highlighted.
The model has been used to perform numerical simulations, predicting cuttings bed heights, pressure drops, and transport velocities at different rate of penetrations and mudflow rates. Results have been compared to predictions by correlation-based models. The observed differences are discussed and improvements on the current model are proposed.
New Down-Hole External Casing Mud Removal Technology Improves Primary Cement Results
Authors: Dillenbeck Robert L. , Simpson Stewart 
Published: December 2007

Abstract
During the course of developing techniques and applications for better primary cementing results, it has become universally recognized that conventional drilling fluids and their residue must be removed from the annular space of a well before an effective hydraulic seal with cement can be achieved. To adequately protect well bore integrity, this hydraulic seal must be effective at both the cement to formation interface, and also at the cement to casing interface. To combat the problem of mud residue on the formation face, a vast array of external casing devices such as formation wipers and scratchers have been developed to help remove this residue through mechanical means. These devices, while effective at mechanically assisting chemical spacers and flushes in mud residue removal from the formation face, do nothing to help clean the exterior of the casing.
Due to its impermeable nature, casing suspended in a well is not subject to the same mud solids build up due to filtrate loss that exposed formations are. However, due to extremely low shear rates at the casing wall, some mud systems can build impressive gel strengths along the casing boundary, and become totally immobile. Experience has shown that this immobile layer can even resist the abrasive flow of cement slurries on the inside of casings, and resulted in the development of the bottom wiper plug commonly used to remove mud residue from inside the casing on many cement jobs pumped today. When this same immobile layer of mud adheres to the exterior of the casing through the placement of cement, the cement can have a very difficult time bonding to the casing and creating the necessary hydraulic seal.
The authors have tested a new mechanical device both under controlled test conditions and in the field, which allows drilling fluid residue to be mechanically removed from the casing exterior both before and during the actual placement of primary cement in the casing annulus. The paper will detail the development of the technology involved, initial testing, and actual field application of the new tools. The results of select field trials where the new devices were run side by side with other older technology will be presented to illustrate the comparative effectiveness of the new technology at achieving improved annular hydraulic seals.