bluuebunny/crossref_metadata_2025_split huggingface dataset:
Lateral Variability in the Corcoran and Cozzette Blanket Sandstones and Associated Mesaverde Rocks, Piceance Creek Basin, Northwestern Colorado
Authors: Lorenz J. C. 
Published: December 2007

ABSTRACT
The widespread sandstone members of the Lower Mesaverde Group (the Iles Formation) in the Piceance Creek basin have significant lateral variability within an overall blanket morphology. This variability can be seen in the Corcoran and Cozzette Sandstone members in the Department of Energy's closely-spaced Multi-Well Experiment (MWX) wells, and can be interpreted from nearby outcrops along the Grand Hogback. Much of the lateral variability consists of thickness changes of both the sandstones and the interbedded lithologies. The number and thickness of depositional units which comprise a bed may change, but the overall sedimentation event is always represented. This type of variation can be ascribed to local variations along widespread, regressive, wave-dominated delta and shoreline environments. Distinctly lenticular sandstones occur in the upper zones of each progradational sequence. These are best represented in the overlying Cameo Coal Member, and can be shown to be distributary channel and splay deposits of a lower delta plain.
The locations of the thickest blanket deposits (the best potential reservoirs) may be a function of the locations of principal distributary systems. For the delta plain deposits, however, the main source of natural gas is the interbedded coals which should be thickest where distributaries were least abundant. Therefore, the best reservoirs for this zone should be in those areas of intermediate sandstone and coal thicknesses.
Prop Transport in Vertical Fractures: Settling Velocity Correlations
Authors: Clark P. E. , Guler Nihal 
Published: December 2007

ABSTRACT
The settling velocity of propping agents is a critical variable in the calculation of proppant distribution in a fracture. Most computer programs available in the industry today base estimates of settling velocity on a Stokes' Law type calculation. We have found that significant deviations from Stokes' Law settling velocities occur In cross-linked fluids and uncross- linked fluids (concentrations in excess of 0.48%).
This paper will discuss experimental results obtained with a dynamic system and the implications which these data have on prop transport calculations. In addition, correlations have been derived which can be used to predict the settling velocities of particles in cross-linked gels. A discussion of these correlations will be included.
Multi-Well Experiment: A Field Laboratory for Tight Gas Sands
Authors: Northrop D. A. , Sattler A. R. , Westhusing J. K. 
Published: December 2007

ABSTRACT
The Multi-Well Experiment (MWX) is a research-oriented field laboratory whose objective is develop the understanding and technology to allow economic production of the several years supply of natural gas estimated to be within the low permeability, lenticular gas sands of the Western United States. Features of MWX include: (1) close-spaced wells (~125 ft,~38 m) for reservoir characterization, interference testing, well-to-well geophysical profiling, and placement of diagnostic instrumentation adjacent to the fracture treatment: (2) complete core taken through the formations of interest; (3) a comprehensive core analysis program; (4) an extensive logging program with conventional and experimental logs; (5) determination of in situ stresses in sands and bounding shales; (6) use of various seismic surveys and sedimentological analyses to determine lens morphology and extent; (7) use of seismic, electrical potential and tilt diagnostic techniques for hydraulic fracture characterization and (8) a series of stimulation experiments addressing key questions. This paper presents the current MWX accomplishments in the above areas since drilling started at the site in September 1981 through December 1982.
Technique for Thermodynamic Crystallization Temperature of Brine Fluids
Authors: Clark D. E. , Hubbard J. T. 
Published: December 2007

ABSTRACT
The application of high density solids free brine fluids has proven to be technically and economically successful in hydrocarbon completion and workover operations. The use of inorganic salts such as calcium chloride, calcium bromide, zinc bromide, and sodium bromide has contributed to the development of complex salt systems. As the density and complexity of these systems becomes more detailed, the requirement for proper fluid design becomes increasingly important.
When a brine solution is cooled sufficiently, a temperature is reached where the solution will be saturated. A further decrease in temperature will result in the precipitation of salt from the solution. The temperature at which this transpires, provided no super-cooling occurs, is the crystallization point of the solution.
A correctly formulated solids free brine should have the optimum crystallization point for the temperature conditions it will encounter. A recently developed semiautomatic procedure constructs a cooling curve plot of each brine tested. This cooling curve plot allows the determination of the super-cooling potential, the Thermodynamic Crystallization Temperature, and the Last Crystal To Dissolve Temperature.
The device provides a permanent record of the cooling curve with repeatable accuracy, which assists in the development of error free brine formulation tables, brine density, and/or crystallization point adjustment, and brine analysis.
Open Cycle Cogeneration Project—Placerita Field
Authors: Doscher T. M. , El-Arabi M. A. , Stiglic Paul 
Published: December 2007

Abstract
The Placerita Oil Field is underlain with thick Pliocene sands containing several hundred feet of oil saturated sand in the Shepard Zone (Saugus) and the Upper and Lower Kraft Zones (Pico). These sands have been exploited somewhat haphazardly since 1920. However, the oil content beneath some of the acreage in the field is of the order of 200,000 barrels per acre. Steam injection will be required to recover the oil, which has a gravity as low as 11° although in some intervals it is as high as 20° API.
Since Placerita is in Los Angeles County, there are many restrictions on what fuel may be used in the steam generators. Natural gas is the preferred fuel, but at this time gas supplies in the area are somewhat more expensive on an equivalent BTU basis than crude oil. In order to be able to contemplate economic development of the field using steam, it is necessary to employ highly efficient processes for burning purchased gas. The scheme that recommends itself is the use of a cogenerator which produces both steam for subsurface injection and merchant electric power.
Tosco Enhanced Oil Recovery Corporation selected GWF Power Systems of Irvine, California to design and install a natural gas-fueled cogeneration system to supply steam and electric power for sale in order to keep the net cost of the former at a sufficiently reasonable level to permit economic recovery of Placerita crude oil by steam injection.
Fluid Management: Predicting and Controlling Viscosity During Weight-Up
Authors: Wilde D. N. , Wilton B. S. 
Published: December 2007

ABSTRACT
This paper presents the development of a procedure that enables the user to predict the increase in plastic viscosity when barite is added to drilling fluid to raise the mud weight. The use of this method makes it possible to adjust viscosity at the lower mud weight when it is more economical to do so.
The equations presented are derived from sound hydrodynamic theory found in the references. Along with the equations, a graph and two handheld calculator programs are included to assist the reader in performing the calculations.
Three-Dimensional Simulation of Steamflooding with Minimal Grid Orientation
Authors: Potempa Thom 
Published: December 2007

Abstract
Steamflooding is a tertiary oil recovery mechanism with proven economic potential. Reliable numerical simulations of candidate injection schemes can aid in the optimization of process parameters. State-of-the-art numerican models exhibit varying degrees of grid effects which affect their reliability with respect to the modeling of pattern floods. This paper presents a numberical steamflood model which does not exhibit a significant amount of grid orientation. This model utilizes a numerical discretization technique which is an admixture of finite difference and finite element methods. Fluid properties are determined as a function of primary variables in a manner that allows a straight forward implementation of Newton's method for solving the nonlinear system of discretized equations. Fractional flows are defined using mass rather than volumetric mobilities, and are used to upwind the convective flow terms.
San Ardo—A Case History of a Successful Steamflood
Authors: Traverse E. F. , Deibert A. D. , Sustek A. J. 
Published: December 2007

ABSTRACT
Texaco's largest steam flood project is in the San Ardo Field in California, and is a model of a successful steam flooding operation. This reservoir still has about 600 million barrels of 11 to 14° API oil in place, and now produces about 20,000 BOPD. The San Ardo Field is located approximately halfway between San Francisco and Los Angeles in Monterey County, California.
Several characteristics of the San Ardo operation make it a rather unique steam flood. But the most unique and significant characteristic relates to demonstrated recoveries of from 40% to over 80% of the OOIP in the active portion of the steam flood. An extension of the performance to date indicates that over 65% to 70% of the OOIP will eventually be recovered. Effective reservoir management, including the development of innovative pattern strategy, and proven operational practices have formed the basis for the current performance.
This paper will review the evolution of the field operation and stress new activities that Texaco is implementing at San Ardo to produce more oil and to do it more efficiently. These activities include a field test of a downhole steam generator.
Surfactant, Polymer, and Alkali Interactions in Chemical Flooding Processes
Authors: Krumrine P. H. , Falcone J. S. 
Published: December 2007

ABSTRACT
Surfactants, polymers and alkaline chemicals are the major components of any chemical flooding process. Interactions of these chemicals can be extremely important to the final outcome of field trials, since the desired effect of each chemical may be enhanced or degraded as the various chemical slugs become mixed in the reservoir. In some instances it may be desirable to inject these various chemicals together in the same slug because of synergistic effects or to shorten the duration thereby improving the economics for the project. It is important to understand and anticipate the nature of these interactions to optimize flood design and recovery performance.
Specific interactions among these chemicals have been examined by interfacial tension (IFT) and viscosity measurements and core displacement studies. Many polymers contain small amounts of surfactant which contribute to IFT reduction, and also polymers slow diffusion and mass transfer to and from the oil and water phases thereby affecting consumption and adsorption phenomena. Certain alkalis have a dramatic effect on the ionic environment which affects both surfactant activity and optimal partioning between phases and polymer hydrolysis, stability, and viscosity. Also alkalis can modify mineral surfaces leading to reduced adsorption of the more expensive chemical components. These observations correlate well with core flood performance where the various chemicals are used either together or in successive slugs of various combination. In general at low concentrations most of these chemicals are compatible with each other and appear to enhance overall performance when used together.
Detection of Linear Impermeable Barriers by Transient Pressure Analysis
Authors: Martinez-Romero Nestor , Cinco-Ley Heber 
Published: December 2007

ABSTRACT
This work presents a new simple method to detect a.linear impermeable barrier by analysis of transient pressure data. This technique is based on the desuperposition method (negative superposition) discussed by some authors and considers the calculation the pressure change caused by the presence of the barrier. The pressure change is analyzed to estimate the distance between the well and the barrier by using the type curve matching technique. Type curves are provided for both drawdown and build tests.
The advantage of the technique presented in this work is that pressure data can be analyzed even if the second semilog straight line, whose slope is twice the slope of the first semilog straight line, is not reached. Examples of application are discussed for illustration.
Stimulating Tight Sands in the Presence of Weak Stress Barriers by Modified Hydraulic Fracturing Techniques: A Status Report
Authors: Ahmed Usman , Strawn Jon , Schmidt Rich , O'Shea Patrick , Veghte Richard 
Published: December 2007

ABSTRACT
Tight gas formations bounded by base rock and/or overlain by an overburden rock, that are not barriers to vertical fracture migration, are not amenable to "successful" large stimulation treatments by hydraulic fracturing as practiced today. Reservoirs of this nature are abundant. The example to be considered here is the North Douglas Creek Arch Field, east of Rangeley, Colorado. The objective of this paper is to present the preliminary findings of a project sponsored by the Gas Research Institute of Chicago and conducted by Terra Tek, Inc. of Salt Lake City and Chandler & Associates of Denver. The program is aimed towards developing technology that can provide deeply penetrating fractures in formations lacking barriers to vertical migration.
Four prospective techniques are being evaluated in the laboratory and in the field: fracture initiation placement (perforation placement), fracture packing with lightweight additives, controlled process zone fracturing, and electrical heating/fracturing followed by hydraulic fracturing. Each of the techniques is being evaluated for feasibility by analysis and tests performed in a polyaxial test machine that is capable of accommodating rock samples one cubic meter in volume. The program intends to validate and optimize the most effective technique in the field. It is anticipated that the optimum technique will probably be a combination of the several proposed techniques. The program includes stimulation technique evaluation in four new wells in the North Douglas Creek Arch Field.
Among the work reported in this paper are: preliminary studies related to the development of the four different techniques, fracture geometry prediction under adverse stress distribution condition, and drilling, coring, drill stem testing, transient pressure testing, in-situ stress measurements, log analysis, and routine and special core testing on core materials from two of the new wells.
Analysis Of The Pressure Behavior Of A Production Well Subject To Interference And Its Application To Reservoir Models
Authors: Thomere R. , Arthur K.B. 
Published: December 2007

Publication Rights Reserved
This paper was prepared for the 40th Annual Fall Meeting of the of the Society of Petroleum Engineers of AIME, to be held in Denver, Colo., Oct. 3–6, 1965. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal, provided agreement to give proper credit is made.
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, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
A method is presented which may be used to analyze the pressure behavior of a well in which some part of the pressure drop is due to interference from other wells in the field. While it is customary to ignore the effects of interference and to assume each well to have a fixed drainage area, it is shown that this approach can produce anomalous results if the production rate of the well in question has varied in a certain fashion. In such a case, it is demonstrated that a consistent analysis is possible only if interference is introduced. As a corollary it is then shown how, under favorable circumstances, the use of an appropriate sequence of flow-rate changes can permit the determination of the interference to which the well is subjected. This determination still permits the average production rate of the well to exceed some 50 per cent of its maximum capability.
The analysis is made possible by the use of a digital computer and is designed primarily to allow accurate matching of field data to a reservoir model. Rather than treat each build-up or flow test separately, we have treated the complete pressure and production history of the well as a unit. In addition, no assumptions need be made regarding reservoir homogeneity or shape. The work described represents a generalization of a previously published analysis, and has been field-proven over a period of several years in the Hassi-Messaoud reservoir in Algeria.

Introduction
The field of Hassi-Messaoud in Algeria, although producing undersaturated oil, poses some difficult problems in the interpretation of pressure behavior. These problems arise because of a combination of extreme heterogeneity, wide well spacing and large changes of skin factor with time. Some four years ago a method of interpretation was introduced, in which a simultaneous analysis was made of all flowing and shut-in pressures measured on a well. As a result of this analysis the effects of changes at the wellbore [skin], were separated from the effects due to the properties of the reservoir around the well.
Effects of Temperature & Pressure Rheology of Less Toxic Oil Muds
Authors: De Wolfe R C , Coffin G B , Byrd R V 
Published: December 2007

Abstract
Studies in the past have looked at the pressure and temperature effects in respect to diesel-based mud systems, but with the introduction of new mineral-base oils, the need for pressure/temperature testing has again become an item of great interest.
Questions have been raised as to the possible differences in characteristics which muds might have in the areas of annular flow dynamics, bit hydraulics, and carrying capacity under actual downhole temperatures and pressures.
The prime reason that there has been little inspection into these areas has been the lack of good base data which could be used in some of the already existing calculation methods available to the industry.
The New Remote-Controlled and Multiangle Bent Sub (Telepilote) for Drilling Trajectory and Corrections
Authors: Boulet J G , Morin P E 
Published: December 2007

ABSTRACT
A down hole adjustable and multiangle bent sub is now available to remotely control the well bore path during directional drilling operations, with he same bottom-hole assembly (BHA) configuration. This new patented tool is called Telepilote. SMF International (SMFI) and the Institut Francais du Petrole (IFP) have developed two different modes of actuation, either by dropping steel balls into the string bore (Mechanical Telepilote) or by sending an electrical signal (Electrical Telepilote).
The paper describes the main dimensional and operational data and procedures and indicates the potential range of application in directional drilling due to the very specific characteristics of this new remote-controlled tool.
Time-Shared Computers For Gas Well Measurement And Control
Authors: Scholes George A. , Darnell Quinton 
Published: December 2007

Publication Rights Reserved
This paper was prepared for the 40th Annual Fall Meeting of the of the Society of Petroleum Engineers of AIME, to be held in Denver, Colo., Oct. 3–6, 1965. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal, provided agreement to give proper credit is made.
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, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Automated gas well control systems, using radio transmission or telephone type cable, have been operated by the industry. The more advanced previous installations have utilized individual computers for each well stream for integration of flow rate from instantaneous orifice differentials and static pressures.
The system described in this paper utilizes time-sharing of a single computer for measurement and control of a number of gas wells and in-plant gas streams. This system includes a centralized control panel with computer, cable transmission links, and transducers at the meter runs for gas flow measurement and control. Return signals from the central control point are used to adjust individual well rates. An accumulated monthly production record is maintained in digit form for each gas stream. Automatic closed-loop control of selected wells maintains the processing plant thru-put at a maximum.
This installation is inexpensive, sufficiently accurate and easy to control. Since accumulated volume for each production unit is displayed at all times, maximum permissible monthly well allowables can be achieved without hand calculation.

EARLIER SINCLAIR SYSTEMS

Radio Control Systems
Various Oklahoma, New Mexico, and Texas gas plants have radio transmission equipment to open and close selected gas wells on signal. None of these systems transmit information back to the control point.

Sligo System
This Louisiana system utilizes electrical transducers at each orifice to transmit differential and static signals by way of underground cable to a central control station.
The Planning, Execution, and Evaluation of Acid Treatments in Sandstone Formations
Authors: McLeod H. O. , Ledlow L. B. , Till M. V. 
Published: December 2007

ABSTRACTPretreatment analysis, job planning, and well preparation lead to acidizing success in sandstones with permeabilities greater than 50 md. Formation mineral analysis improves success in sandstones with lower permeabilities. Injection pressure responses to acid injection provide data for onsite decisions.