bluuebunny/crossref_metadata_2025_split huggingface dataset:
Colorado River Water-Energy-Politics
Authors: Fischer Roland C. 
Published: December 2007

Abstract
The Colorado River is one of the most controlled, one of the most controversial and the most litigated river in the world. Its limited water resources are the subject of intense competition for irrigation and municipal uses and soon that competition will increase as the energy resources of the Colorado River Basin are developed to help meet the energy challenges facing the United States. The competition for the waters of the Colorado River has been growing since before the turn of the century and shows no signs of decreasing. Historically, that competition has to a large extent been resolved in one political arena or another and like the competition, the politics surrounding Colorado River water show no signs of decreasing. Although a great deal has been written about the "Law of the River" which is generally thought of as meaning the two Congressionally-approved interstate compacts, (1922 and 1948); one international treaty (1944); and, the laws of the 7 states that comprise the Colorado River Basin, politics and to a fairly large degree emotion, have been a significant and often controlling means by which the waters have been allocated and applied to beneficial use. The seven basin states are California, Arizona and Nevada in the Lower Basin (below Lee Ferry, Arizona) and Colorado, Wyoming, Utah and New Mexico in the Upper Basin (above Lee Ferry, Arizona). Arizona and Utah are hydrologically partly in the upper and Lower Basins
The first of the landmark documents dealing with the division of the waters of the Colorado River and agreed to by the seven states and the United States is the Colorado River Compact of 1922, which provides for the equitable division and apportionment of the use of the waters of the Colorado River system. Even then California was growing faster than the other basin states and politics played an important role in the way the compact was finally ratified. Today California waters approximately 11 million people with Colorado River water and has 45 members in both houses of the United States Congress; Colorado has 7. These numbers speak volumes politically.
The Upper Basin states recognized early on that they would have to agree to apportion their waters by a more specific formula and in 1948 entered into the Upper Colorado River Compact which apportions the water among the 4 Upper Basin states: Colorado, 51.75%; New Mexico, 11.25%; Utah, 23%; Wyomong, 14%. This compact establishes the Upper Colorado River Commission and the Upper Basin states fund it in the same ratio as their share of the water. However, when the Upper Colorado River Basin Fund was established by the Colorado River Storage Project Act in 1956 the states agreed to share the fund with 46% to Colorado; 21.5% to Utah; 15.5% to Wyoming and 17% to New Mexico. Politics was instrumental in the decision to share the water and the money on different bases.
Prediction of Deliverability from a Multi – Well Gas Reservoir
Authors: Baldwin James O. 
Published: December 2007

ABSTRACT
This paper describes a technique for accurately predicting gas deliverability from a multi-well gas reservoir. The computer program listed in APPENDIX A will simulate a gathering system which has a gas reservoir being drained with multiple wells and compressor stations – for example, an offshore gas reservoir being exploited by several platforms with each platform having its own compression facilities. By using this program, Marathon Oil Company has been able to quickly and accurately predict gas deliverability from an offshore gas field located in the Gulf of Mexico with varying horsepower availability at each compressor facility as well as account for increased well deliverability resulting from workovers, well recompletions, stimulations, etc.
A Method for Appraising the Feasibility of Field-Scale CO2 Miscible Flooding
Authors: Drennon M. D. , Kelm C. H. , Whitington H. M. 
Published: December 2007

ABSTRACT
Amoco Production Company is actively investigating the potential for recovering tertiary oil. This paper describes the evaluation process of scoping studies performed to determine the economic feasibility of CO2 flooding West Texas properties which are currently being depleted by waterflood operations. This method was applied to the evaluation of eleven Amoco operated properties in seven fields in the Permian Basin, encompassing 2300 producers and 1600 injectors. Also included in this paper are a number of technical, operational and practical concerns which have been identified during the evaluation process.
The procedure used to evaluate the feasibility of CO2 flooding a property, as described herein, is as follows: 1)Develop a reservoir description by using a reservoir simulator to match past waterflood performance. Requisite to this process is an understanding of the performance being simulated.2)Predict future waterflood performance.3)Predict tertiary performance by employing a simulator of miscible CO2 displacement which contains the previously developed reservoir description.4)Generate incremental tertiary economics using predicted tertiary rates and reserves, along with estimates of necessary investments and operating costs.
This paper includes a discussion of the methods used to match past waterflood performance of entire properties. Where available, geological data was incorporated in developing reservoir descriptions. Detailed geological evaluations of the properties are in progress which are expected to contribute to and support future refinement to the performance derived reservoir descriptions. In several cases, completed geological evaluations support the reservoir descriptions generated through performance matching. Amoco has an extensive pilot program underway in West Texas which will demonstrate the validity of the prediction technique and provide data for development of improved prediction methods.
Invariant Imbedding Identification of a Dynamic Rock Fracture/Drilling Model
Authors: Eronini Iheanyi E. 
Published: December 2007

ABSTRACT
The Invariant Imbedding Technique was used to simultaneously identify rock and rock-bit parameters and estimate the state in a dynamic rock fracture model applied to the bit tooth drop test. The results indicate possible Improvements to the rock description and suggest that this model may be adequate for drilling data analysis. Also application of the method to rotary drilling and bottom-hole measurement systems is possible but it is limited by the required data rates.
Occurrence and Distribution of Overpressures in the Northern North Sea Area
Authors: Lindberg Per , Riise Raoul , Fertl Walter H. 
Published: December 2007

ABSTRACT
Detection and evaluation of abnormal formation pressures is critical to exploration, drilling, and production operations.
Occurrence and distribution of abnormally high-formation pressures encountered in the exploration for hydrocarbon resources has been studied on a regional basis in the Northern North Sea. Detailed data on subsurface pressure environments encountered in wells drilled in Norwegian and U.K. waters are presented for the Viking Graben, East Shetland Basin and the Bergen High.
Global, A New Approach to Computer-Processed Log Interpretation
Authors: Mayer C. , Sibbit A. 
Published: December 2007

ABSTRACT
A new computer-processed log interpretation chain, GLOBAL, uses a structure independent of model and logging suite. An error model is defined relating tool measurements to petrophysical parameters such as porosity, lithology, and fluid saturation. Then, using a minimization routine, GLOBAL searches for the solution with the minimum error. This solution is considered the most probable answer.
A quality curve is presented indicating how well the answers fit the chosen model. The curve helps to determine if the model is inadequate, or if insufficient information is available to solve the interpretation problem.
The main advantages shown by the examples analyzed are: Simultaneous use is made of all combination of logs, including experimental or recently introduced sensors.The approach works for very complex litholo-gies.It is adaptable to all kinds of models and local conditions.
Oil Field Operational Control Systems
Authors: Hodge Bartow , Hodgson Robert N. 
Published: December 2007

Publication Rights Reserved
This paper is to be presented at the 39th Annual Fall Meeting of the Society of Petroleum Engineers on Oct. 11–14, 1964, in Houston, Tex., and is considered the property of the Society of Petroleum Engineers. Permission to publish is hereby restricted to an abstract of not more than 300 words, with no illustrations, unless the paper is specifically released to the press by the Editor of JOURNAL OF PETROLEUM TECHNOLOGY or the Executive Secretary. Such abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in JOURNAL OF PETROLEUM TECHNOLOGY or SOCIETY OF PETROLEUM ENGINEERS JOURNAL is granted on request, providing proper credit is given that publication and the original presentation of the paper.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and considered for publication in one of the two SPE magazines with the paper.

Abstract
This automation system provides for automatic custody transfer, well testing, surveillance, and supervisory control for leases and individual wells.
Each well is automatically switched to gauge in a programmed sequence and for a programed time duration; to determine the net oil, water, and gas production of each well; to transmit this data via wire line or microwave to a central office where it is processed and stored in the computer's memory; and to provide weekly and monthly production reports.
Automatically clean, measure, and ship crude production from cleaning plant to pipeline departments; furnish cleaning plant oil inventory and chemical usage in treating, daily and on demand.
Automatically check all critical points of operation at guage and tank settings and advise location and nature of any malfunction, monitor each well's flow and transmit alarms to central office for determining well producing days as well as malfunction information. This includes local control, remote control, and computer control.
— Data shall be automatically accumulated in the field, transmitted to the central point, and processed as required for operations and accounting needs.
—Overriding the above considerations are:
Reliability Expandability Ease of Maintenance Training of operating and maintenance personnel.

Introduction
Oil Field Management - The New Way.
Single integrated systems that monitors and controls oil field operations at widely separated points on a round-the-clock basis and, at the same time, provides advanced data processing services to both management and engineering personnel, are now becoming reality with present day computers and instrumentation equipment.
Computers, such as the IBM System/360 now offers in a single system the compatible, expandable, monitoring, processing, control, and communication abilities needed.
Solar Powered Injection Controller Utilizing Bottom Hole Pressure Sensing Device
Authors: Treadway Robert B. , Roye J. E. , Westerman G. Wayne 
Published: December 2007

ABSTRACT
An innovative new water injection controller has been developed which will significantly improve water injection into wells, especially those exhibiting no measurable surface pressure. The new system consists of a motor control valve, turbine meter, injection controller, and bottom hole pressure (BHP) device, with power supplied by a solar panel, negating the need and added expense of running power to each well. The new system has the capability to monitor well BHP, compare the BHP against a preset value, and adjust the injection rate accordingly. The system will eventually have the capability to run step-rate tests and pressure fall-off tests automatically, as well as perform temperature surveys. Since the unit is installed in the tubing in much the same manner as a wire line tool, no pulling unit expense is incurred.
Modelling Reservoir Geometry with Non-Rectangular Coordinate Grids
Authors: Wadsley W. A. 
Published: December 2007

ABSTRACT
This paper describes a practical method for using non-rectangular grids in reservoir simulation. Such grids can easily be constructed for two- or three-dimensional studies: for example, when the boundary of the reservoir is irregular; or, when the reservoir layers have varying thickness across the reservoir; or, to approximate principal fluid-flow directions such as in pattern displacements. Although use of such grids has been described before, the need for analytic calculation of coordinate functions, or the calculation of coordinate derivatives, has previously precluded the routine use of these methods.
In the present case a novel construction for non-rectangular grid systems is presented. This consists of approximating an orthogonal curvilinear coordinate system by straight line segments. The curvilinear system is not analytically derived but is drawn by the engineer to conform to irregular geometry and porosity and permeability trends. A new method for calculating inter-block transmissibilities and block pore-volumes is given. Other topics covered include changing grid systems during simulation, use of a radial grid in the vicinity of every well in a reservoir and convergence of a curvilinear grid in 1/8th of a five-spot pattern. Use of the method is illustrated by a heavy-oil steam-flood in a dipping symmetry element of a seven-spot pattern.
The Dielectric and Conductivity Response of Sedimentary Rocks
Authors: Sen Pabitra N. 
Published: December 2007

ABSTRACT
We calculate the complex dielectric constant of brine saturated sedimentary rocks using several different models. A calculation using a self-consistent scheme gives Archie’s law in the d.c. limit. The cementation exponent, m, is shown to depend on grain shape, in agreement with experiments. The theory also agrees well with dielectric constant and conductivity measured at 1.1 GHz on fused glass heads. It is shown that by including special geometrical features, such as high aspect ratio particles, the experimentally observed salinity and frequency dependence and the extremely high values of dielectric constant at low frequencies can be explained. Rigorous bounds on the dielectric and conductivity values of a rock composite also show that large values of dielectric are possible. The polarization of the ions at the rock-water interface equally give rise to high values of dielectric constant.
A Practical Short-Term Interference Testing Method to Determine Reservoir Heterogeneities
Authors: Bandyopadhyay Pratip 
Published: December 2007

ABSTRACT
Interference testing is widely used in the petroleum industry to obtain reservoir descriptions vital to the evaluation of proposed tertiary recovery projects. A new analytical method that provides an accurate reservoir description and requires only early time data was developed for this purpose. This method worked very well when applied to data from the literature and was successfully applied in the design, monitoring and analysis of interference tests conducted in a mid-continent field.
The conventional method of interference test analysis involves the application of a complex exponential integral function fit of the data to "type curves" either by least squares on a computer or by transparent overlays. In the new technique, the early interference data from each well are fit with a straight line. The slope of the straight line is then used to compare the degree of interwell communication. A practicing engineer with a pocket calculator can successfully use this method to design, monitor and analyze interference tests.
The method is particularly useful in reservoirs of wide spacing where the interference testing period can be inordinately long even when a highly sensitive pressure gauge is used. With judicious application of this technique, the test duration can be minimized considerably thereby reducing testing costs and delayed production.
The method is rigorously developed and a field example is given.
Air Injection Into a Mature Waterflooded Light Oil Reservoir. Laboratory and Simulation Results for Barrancas Field, Argentina
Authors: Pascual M. , Crosta D. , Lacentre P. , Coombe D. 
Published: December 2007

ABSTRACT
This paper describes preparations for an air injection pilot into a mature waterflooded light oil reservoir in Barrancas field, Argentina. Primary development started in 1954, with waterflooding beginning in 1967. As the reservoir characteristics are quite similar to economically viable air injection projects in the Williston Basin, the feasibility of air injection for Barrancas was investigated. The upper layer has contributed 40 % of the total field production with 46 % of the injected water entering into the sequence. The three lower zones appear to be good candidates for air injection due to their current high oil saturation.
Laboratory studies carried out at the University of Calgary were aimed at determining pilot design information (self-ignition, fuel availability, air requirements). These included accelerated rate calorimetry, ramped test oxidation, and high pressure/high temperature combustion tube tests. The combustion tube showed excellent burning characteristics (temperature profiles &gt;300 °C). A reasonable simulation match was obtained using compositional PVT from Barrancas to define the component description. The laboratory simulations were then used to explore various additional sensitivities.
The history match model consisted of a target pilot zone of six inner producers surrounded by additional outer producers and numerous water injectors. The four sequences were separated with transmissibility barriers of varying strength, and also contained channels with permeability enhancements. The magnitudes of these factors and the water-oil relative permeability characteristics were adjusted during the history match.
The black oil reservoir description was then converted to the thermal/compositional representation for the air injection sensitivity runs. Several air injection scenarios with two air injectors were considered, including variation in air injection rates and injection completion zones, and wet combustion as a follow-up to dry.
According to the results of this study, the process is technically feasible. Currently the economic aspects are being studied before pilot implementation.
History Matching Reservoir Models Simulated from the Pluri-Gaussian Method
Authors: Thomas P. , Le Ravale-Dupin M. , Roggero F. 
Published: December 2007

Abstract
Gaussian-related random realizations are widely used in petroleum engineering to describe permeability or porosity distributions in underground reservoirs. Except by luck, flow simulations run for these realizations do not yield numerical answers reproducing the measured dynamic data such as well pressures, flow rates, water cuts… Realizations must be modified to become consistent with the field data, which is done through an optimization process. The gradual deformation method (GDM) is a geostatistical parameterization technique introduced to change continuously Gaussian-related realizations from a few parameters while preserving the two-order statistics. In this paper, we focus on realizations simulated from the pluri-Gaussian method and we show how to apply the GDM to modify such realizations.
The pluri-Gaussian method, which is an extension of the truncated Gaussian method, is used for generating facies realizations. It shows the same general features as the truncated Gaussian method, but with a wider range of possibilities especially in terms of complexity for the generated realizations, making it possible to better represent reservoir heterogeneity. The simplest scheme followed by the pluri-Gaussian method, which is presented here, involves the transformation of two starting Gaussian realizations. The GDM can be exploited to modify both realizations independently or simultaneously. Additionally, this modification may be global or local. In other words, the GDM can be used to change the whole pluri-Gaussian realization by globally changing either one or both of the starting Gaussian realizations. It can be used also to change given subdomains of the pluri-Gaussian realization by locally changing either one or both of the starting Gaussian realizations. This capability provides a substantial flexibility to the matching process. The suggested methodology is validated on synthetic test cases, which stress the efficiency of the suggested methodology in terms of model simulation and history matching.
Fast Estimation of Performance Parameters in Fractured Reservoirs Using Percolation Theory
Authors: Masihi M. , King P. R. , Nurafza P. R. 
Published: December 2007

Abstract
Fractured reservoirs have heterogeneities on all length scales which affect all aspects of flow and make the reliable prediction of reservoir performance extremely difficult. The conventional approach to this is to build a number of possible reservoir models (with associated probabilities) then upscale them and run flow simulations. The problem with this approach is that it is computationally very expensive.
An alternative approach derived from percolation theory to make a very rapid estimation of reservoir performance and its uncertainty using sandbodies as flow unit was introduced by King et.al1-2. This approach is based on the permeability contrasts that control the flow and assumes that the permeability disorder can be approximated by either permeable or impermeable rock. The advantage is that by using some semi-analytical universal curves from percolation theory the effect of the complex geometry which influences the performance parameters can be easily estimated in a fraction of second on a spread sheet.
This study extends the application of this approach to fractured reservoirs where we can assume that matrix is almost impermeable and fracture is highly permeable. The problem with this extension is that classic percolation can not be used due to spatial correlation of fractures. However for correlated systems, the basic methodology with some modifications, which in turn depend on the nature of correlation, can be applied. We develop a stochastic methodology based on the derived spatial correlation by Heffer et.al3 to generate fracture network realizations. Then by using this spatially correlated model we use the same basic algorithm of percolation theory in 2 and 3D. Simulation results show the applicability of this approach to fractured reservoirs. Moreover we show how to include the effect of anisotropy in the universal curves in order to assess uncertainty in anisotropic reservoirs.