bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluation and Implementation Of CO2 Injection at the Dollarhide Devonian Unit
Authors: Poole E. S. 
Published: December 2007

ABSTRACT
A carbon dioxide (CO2) injection project has been underway at the Dollarhide Devonian Unit since May 1985. Through August 1987, 5.8% hydrocarbon pore volume (HCPV) of single slug CO2 had been injected into the Unit's Phase I CO2 area with very little breakthrough at producers. Dollarhide's total lack of premature breakthrough is unique among West Texas CO2 floods and is indicative of unusually high CO2 sweep efficiency. Through pattern realignment and injection of a 30% HCPV of CO2, the project is expected to recover 19% original oil in place (OOΙΡ), or 26.3 MMSTB.
Prediction of Waterflood Performance in Stratified Reservoirs
Authors: Tompang R. , Kelkar B. G. 
Published: December 2007

ABSTRACT
Crossflow between adjacent layers plays an important role on water flooding performance in a stratified reservoir; however, the analytical solutions describing the crossflow effect are possible only under limiting conditions: (i) where viscous forces are dominant (no crossflow); and (ii) where vertical equilibrium exists (gravity and capillary dominated displacement). This study analyzes the effect of crossflow on the waterflooding performance by comparing simulator results under actual flooding conditions with the approximate analytical solutions. The parameters varied include the injection rate, vertical permeability variation, ordering of beds, mobility ratio and the ratio of vertical to horizontal permeabilities. A five beds, linear model was used under wide range of operating conditions.
Based on the study, it was observed that the oil recovery and cross flow index were dependent on the value of RL (effective length to height ratio) for favorable mobility ratios, and on the value of RD (vertical to horizontal pressure gradients ratio) for unfavorable mobility ratios. Ranges of RL and RD were established for which approximate analytical solutions are valid. For the intermediate region (where both viscous and gravity forces are important), empirical correlations for crossflow index were developed.
New Techniques Lead to Better Completions in Red Fork and Other Low-Permeability Formations
Authors: Rose R. E. 
Published: December 2007

ABSTRACT
The Red Fork, a member of the Pennsylvanian age Cherokee group in western Oklahoma and the Texas panhandle, has been the target for major drilling and completion activity for several years. During 1979-81, several wells were completed in the Red Fork with varied results. The history of these completions and treatments has been traced and determinations have been made as to why post-1981 completions have shown better results than pre-1981 completions. From these results and with the aid of computer monitored pump-in/flow-back tests, the Red Fork may be "typed" by an empirically derived correlation. Thus completions can be designed for this particular "typed well" response.
With the information obtained from the pump-in/flow-back test (i.e., maximum proppant concentration, maximum pumping time, and fracture closure pressure), a stimulation treatment may be designed for maximum proppant placement. After placement of the proppant, a technique may be applied to induce closure so proppant is trapped in the producing interval instead of depositing in the bottom of the induced fracture, which may not be a portion of the producing interval. An example would be a large shale section or a section having such low permeability or porosity that is below the perforated section such that production may be below the economic payout of the well.
This paper presents (1) field treatment histories, (2) analysis of completion success pre-and post-1981, and (3) methods of job design to help achieve maximum proppant placement in the Red Fork Formation.
The Critical Production Rate in Water-Coning System
Authors: Abass H. H. , Bass D. M. 
Published: December 2007

ABSTRACT
Water coning is the mechanism in which the oil/gas – water contact locally rises toward the perforated interval in a partially penetrated oil/gas well.
Numerical and physical models have been built to study the performance of water coning under different boundary conditions. A fully implicit, strongly coupled mathematical model was formulated to handle rapid pressure-saturation changes. On the other hand, a plexiglass model was constructed to obtain a qualitative and quantitative description of water-coning phenomenon. An analytical description of water coning under different flow conditions was developed.
Sucker Rod Pumping Unit Diagnostics Using an Expert System
Authors: Derek H. J. , Jennings J. W. , Morgan S. M. 
Published: December 2007

ABSTRACT
This paper presents an application of expert system technology to diagnose sucker rod pumping units. This approach helps to capture expert's knowledge, often held by a few individuals, and make it available wherever a personal computer is available. The captured knowledge becomes permanently recorded and can be updated as the system solves more difficult problems.
A rule-based expert system has been developed to help the user analyze the subsurface pump problems. Based on interviews with an industry recognized beam pumping expert diagnostic rules were formulated to identify problems within the subsurface pump. The system utilizes auxiliary programs to obtain information necessary in the analysis process. The user is also given access to the information obtained from the expert thereby transfering the expert's knowledge to the user.
Three-Phase Relative Permeability Correlations
Authors: Baker L. E. 
Published: December 2007

ABSTRACTSeveral correlations have been proposed for prediction of three-phase relative permeability from two-phase data or from saturation/capillary-pressure relationships. These include the models of Stone, Hirasaki, Corey et al., Naar and Wygal, Land, Aleman, and Parker et al. This paper compares predictions of these models with predictions of two additional models (saturation-weighted interpolation and true-linear interpolation). The comparison is made using all the published three-phase experimental relative permeability data complete enough for application of the models.The comparison shows that the models are often not very good predictors of the experimental data. This points out a need for better relative permeability models in cases where three-phase flow may have a significant effect. In most cases, straight-line interpolation or saturation-weighted interpolation between the permeabilities at the two-phase boundaries of the three-phase flow region provided a better fit of the experimental data than did the theoretically-based models.The paper also demonstrates the utility of comparing the effects of different relative permeability models before using them in a reservoir simulation. Sometimes the result of a simulation can be heavily biased by the choice of relative permeability model used.
Offshore Operations In Cook Inlet, Alaska
Authors: Goepfert B.L. 
Published: December 2007

This paper was prepared for the 96th Annual AIME Meeting to be held in Los Angeles, Calif., Feb. 19 through 23, 1967. 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 requested 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 discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Offshore operations in the hostile environment of Cook Inlet, Alaska, began in 1959 with the joint seismic surveys of some 11 companies in the waters of the upper Cook Inlet. In 1962 several companies drilled exploratory wells on leases purchased in 1961. The first all-weather, all-year drilling and production platform was installed in the Inlet in the fall of 1964. Presently there are six platforms operationally complete, one partially completed, and four planned for installation in 1967, for a total of 10 drilling and production structures in the Inlet by the end of 1967. The first crude oil flowlines were installed in 1965 and many more additional lines were added in 1966, with plans to re and expand the flowline network in 1967.
The problem associated with Cook Inlet which set it apart from other offshore areas are related to the remoteness of the area from support facilities and the hostile environment, specifically the 30-foot tidal range and accompanying swift currents, and the range of temperatures which cause the Inlet to ice over in the winter months.
Nevertheless, progress is being made in developing the mineral resources underlying the Inlet and solutions are being found for the many special problems which should eventually enable the efficient drilling and production of the hydrocarbon resources hidden under the icy waters of the Inlet.

Introduction
In 1959 some 11 oil companies shared the cost of obtaining basic seismic data in the upper Cook Inlet, thus beginning one of the most challenging drilling and production programs in the history of our far-ranging search for reserves of energy to provide the ever-increasing demands for fuel needed in our modern society.
Kinetics of Silica Dissolution and Hydroxyl Ion Consumption In Alkaline Flooding
Authors: Saneie Shahrouzeh , Yortsos Y. C. 
Published: December 2007

ABSTRACT
In this paper a mathematical model simulating the kinetics of silica dissolution and hydroxyl ion consumption in a typical alkaline flooding environment is developed. The model is based on the premise that dissolution occurs via hydrolysis of active sites through the formation of an intermediate complex, which is in equilibrium with the silicic acid in solution. We consider equilibrium ion exchange at the silica surface and ionization reactions of the silicic species in solution. Both static (batch) and dynamic (core flood) processes are simulated to examine the sensitivity of caustic consumption and silica dissolution to process parameters, and to determine rates of propagation of pH values.
The model presented provides a quantitative description of the quartz-alkali interaction in terms of pH, salinity, ion exchange properties, temperature and contact time, which are of significant importance in the design of soluble silicate flooding processes. The latter are shown to minimize or eliminate silica dissolution and caustic consumption, in agreement with recent suggestions. An analysis of the batch processes shows that OH- consumption results from a combination of both ion exchange and silica dissolution. Higher values in the salinity level and in the ion exchange constant lead to a net increase in OH- consumption despite the decrease in the dissolved silica.
The opposite effect arises in core flood processes, where the ion exchange is beneficial in arresting the OH- consumption and the decline of pH, in an upstream region. This (plateau) region is characterized by a constant concentration of Na+, the silica-alkali interaction follows a batch-like behavior and pH profiles become stabilized. A region of decline to the initial values precedes this ion exchange plateau. For all practical purposes, the relevant quantities are the pH level at the front of this plateau, determined from the batch analysis, and its velocity of propagation. Thus, the rate of the pH decline increases with the Damkohler number (C), and equilibrium pH values may be reached well before breakthrough for high enough C. The equilibrium values are independent of salinity or the ion exchange constant, although the conditions for establishing the equilibrium before breakthrough and the frontal velocities are functions of these parameters. For instance, the front velocity is found to decrease as the ion exchange constant increases.
An Improved Cyclic Steam Stimulation Model for Pressure-Depleted Reservoirs
Authors: Sylvester N. B. , Chen H. L. 
Published: December 2007

ABSTRACT
An improved cyclic steam stimulation model for predicting heavy oil recovery from pressure-depleted reservoirs is presented. The model incorporates many of the advantages of existing models with some important modifications and improvements. A modified gravity drainage inflow equation is used to predict the production rates for both oil and water. The heated radius equation is obtained by modifying the original Marx-Langenheim relation to account for wellbore heat loss during injection and for the heat remaining in the reservoir from previous cycles. A new water saturation equation, which includes condensed steam from previous cycles, is presented to simulate changing saturation during production. The model permits the direct input of field data or correlations for relative permeability versus water saturation.
Utilizing only one adjustable parameter, the model produces an excellent history match of oil production and water cut for the seven cycle, Midway Sunset field test. In addition, the model is shown to reliably predict oil production without the need to adjust field data.
A Simplified Modeling Study of Vickers East Waterflood Project in Inglewood Field
Authors: Sankur V. , Emanuel A. S. 
Published: December 2007

ABSTRACT
This paper describes and evaluates the application of stream tube modeling techniques to historical and projected waterflood response for the Vickers East reservoir in the Inglewood field. The technique was successful in predicting the past production history and WOR behavior through the initial flood and the subsequent realignments.
Vickers East, like most other L. A. Basin reservoirs, has a complex geology. It is characterized by up to 1400 feet of gross thickness, cut by numerous faults and composed of very thin sand and shale beds. The field has been under waterflood since 1955 and had three realignments in its history. To evaluate waterflood performance and to assist reservoir management, a modeling study was initiated. Due to time and cost requirements, a 3-D fieldwide finite difference simulation study was considered impractical.
Despite the complexity of the reservoir, a relatively simple stream tube model was developed to represent historical performance and to predict response to a recent realignment project. The model uses a numerical solution for the stream function equation and an approximate mapping technique to reflect the change in streamlines as wells are drilled or converted. The geology was represented by six equivalent layers determined from the field measured Dykstra-Parson's coefficient of 0.6.
The past performance was matched well by using historic gross fluid rates, with minor parameter adjustments. The model was used to predict the response of the latest realignment. The early field performance lags the production forecast for reasons explained in the text.
This study demonstrates that stream tube methods can be effective in designing new waterfloods or realigning old ones in complex reservoirs. Various scenarios can be run at low cost to guide realignment decisions and the production response--with some modifications-- can be used in economic analysis. This methodology offers more flexibility than decline curve analysis and much lower cost than rigorous 3-D finite difference simulation.
Optimizing Cement Design for Improved Job Results
Authors: Evanoff J. I. , Cook C. 
Published: December 2007

ABSTRACT
Until recently, wells in the northern Sacramento Valley had often been troubled by interzonal communication, as evidenced by poor bond logs necessitating frequent remedial cement work. Cement designs commonly used in this area proved ineffective in solving this problem. Analysis of the cementing failures in this gas field led to the realization that a total reevaluation of the cementing program for this field was required to determine the nature of the poor cement job results obtained.
An effective cementing program was eventually developed based upon findings published in research papers on cementing practices, and on field experience already obtained in this particular area. This cementing program focused on cementing practices including displacement mechanics, slurry design, and physical elements such as cement column length. Through a thoroughly engineered approach to well evaluation and cement job design, a consistent methodology for cementing practices was developed. Two key elements of the successful cement design included use of controlled fluid loss cement slurries, and short cement column lengths.
Though this paper presents a summary of field experiences specific to the conditions prevalent in the northern Sacramento basin, the methodology should be applicable to any given set of conditions either on a field-wide or individual well basis. An examination of this analytical, problem solving cementing design technique will show operators and service companies a method to help minimize job design flaws, and to optimize cementing results.
The Characteristics of a Low Temperature In Situ Shale Oil
Authors: Hill George R. , Dougan Paul 
Published: December 2007

Abstract
A 40 degrees A.P.I. crude shale oil has been produced from the Green River Formation in the Piceance Creek Basin of Colorado by injection of hot natural gas at a controlled temperature. The quality of the shale oil differs very markedly from the customary shale oil from the same formation produced in a high temperature retort. The characteristics of the oil fractions have now been determined. These include distillation analyses, viscosity, and pour point determination.
Kinetic data on the production of the shale oil under the conditions used in the field, but carried out on a small scale in the laboratory will be presented. A possible mechanism for the production of this oil, as well as a mechanism for the production of shale oil by more usual high temperature methods will be presented.

TEXT
Various methods for the production of shale oil by in situ techniques are being investigated in the United States. The method with which this paper is concerned involves the use of hot natural gas as the energy conveying medium to convert the kerogen in the oil shale to a petroleum like liquid. The basic concept, which was developed by the late J.L. Dougan of Equity Oil Company and tested in the Fuels Engineering Department laboratories at the University of Utah and subsequently field tested in the Piceance Creek Basin of Colorado, is basically a low temperature conversion and distillation process. Natural gas is heated to a temperature below its thermal decomposition temperature and injected through an insulated pipe into the Green River Oil Shale formation where it loses its heat rapidly to the oil shale, gradually raising the temperature of the shale toward that of the injected gas. The kerogen is converted to bitumen and finally to a low pour point, high gravity crude oil.
Since the temperature of the natural gas is below that for thermal decomposition of the mineral carbonates in the oil shale, little CO2 is produced. The natural gas is compatible with the oil, being soluble in it; this aids in the penetration of the formation by the natural gas and in the heat transfer. Since the heating gas is completely free from oxygen, no oxidation induced polymerization of the oil occurs.
Prior to the field experiment, oil shale cores from the Piceance Creek Basin were heated in a natural gas stream under two conditions. Some experiments were run at a gas pressure of 300 lb/sq. inch.
New DAP Mud System Shows Promise for Rocky Mountain Environmentally Sensitive Areas
Authors: Vesely D. P. 
Published: December 2007

ABSTRACT
The introduction of new polymers such as partially hydrolized polyacrylamides (PHPA) and sulfonated acrylates has led to the development of a clay-free DAP/Polymer system. The DAP/Polymer system can be used in place of KCL/Polymer in the Rockies to achieve nearly the same shale stability and has some distinct advantages as compared to KCL/Polymer muds: DAP muds are more enviornmentally acceptable.DAP muds are less corrosive.DAP muds have resistivities nearer to fresh water, facilitating log interpretation in some instances.
Predicting Power Cost and its Role in ESP Economics
Authors: Pankratz R. E. , Wilson B. L. 
Published: December 2007

Abstract
With the current pressure on profitability, the economics of oil production are being closely scrutinized by most producers. This paper develops a method for estimating the power cost for electrical submersible pumping systems (ESP's) and views the role of power cost in the overall picture of economics for this type of artificial lift. To validate the procedure that is used, the calculations have been compared to actual data taken from field tests of operating ESP's.
This paper is directed toward the Engineer who is responsible for the selection of artificial lift equipment. To increase the utility of the method, it uses only data published by the equipment manufacturer and well established calculating routines.
The total economic picture of artificial lift would have to include many factors which are beyond the scope of this paper. This paper will limit itself to the factors that are involved in the choices an Engineer has to make in the selection of ESP's.
Application of Laplace Transformation to Elliptical Flow in Naturally Fractured Reservoirs: Part I-Theoretical Treatment
Authors: Okoye C. U. , Oyefodun A. , Matese J. J. , Hayatdavoudi A. , Ghalambor A. 
Published: December 2007

ABSTRACT
This paper presents new analytical solutions to unsteady state and pseudo-steady state flow in naturally fractured reservoirs whose boundaries can better be approximated by elliptical rather than linear or radial coordinates. While elliptical flow may occur in several geometric systems, fractured reservoirs are believed to exhibit elliptical flow behavior, particularly during the transitional period. Directional permeability inherent in fractured reservoirs creates reservoir anistropy. Flow from anistropic reservoir towards a circular wellbore will be elliptical rather than radial.
In this study the pressure pattern of naturally fractured reservoir is considered to develop under the assumption that allows matrix to fracture cross flow to result from a diffusion mechanism of fluid transfer through the matrix. The constant rate pressure distribution equations developed in this study were coupled to skin and wellbore storage parameters.
Type curves which can be used for well test analysis were generated with results of various analytical solutions. In the second part of this study, presented in the part two paper several field pressure data were analyzed using these type curves and the results compared with those obtained from type curves generated using radial or linear model solutions.