bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Effect Of Potassium-Salt Muds On Gamma Ray, And Spontaneous Potential Measurements
Authors: Cox J.W. , Raymer L.L. 
Published: December 2007

Abstract
Interpretations of the Gamma Ray and Spontaneous Potential curves generally assume sodium chloride to be the dominant salt in both the formation water and the mud filtrate. However, potassium-salt muds are increasingly being used by the oil industry. The potassium cation is significantly different from the sodium cation in its radioactive and electrochemical properties.
Natural potassium contains a radioactive isotope which emits gamma rays. Thus, the presence of potassium salts in the mud system may contribute to Gamma-Ray tool response. Since the Gamma Ray is used quantitatively in many geological sequences as an indicator of clay content, a way to correct for the effect of potassium in the mud column is desirable. Correction methods and charts based on Laboratory measurements and field observations are presented ba this paper.
The effect of temperature on the resistivity of potassium muds is also briefly discussed. From data available, it appears to be similar to that for NaCl muds.
On the bases of field odservations and laboratory work, the electro-chemical properties of potassium-chloride and potassium-bicarbonate muds and mud filtrates are discussed. Activity relationships are proposed, and the influence of these salts on the SP component potentials—namely, the liquid-junction, membrane, and bi-ionic potentials—is described.
Field examples are presented.
Chemical Systems for Water and Gas Control: Terminology, Evaluation Methods, Candidate Selection, and Expectations
Authors: Botermans C. Wouter , Dalrymple E. Dwyann , Dahl J. , Smith David 
Published: December 2007

Abstract
Because water and gas production often causes reservoir, wellbore, and surface facility problems, controlling water and gas production is a primary concern for hydrocarbon producers.
Problems associated with water and gas production have triggered many companies, research institutions, and universities to study water- and gas-production problems and develop chemicals and mechanical products that can control these problems. Because of the varieties of studies and products there are differences in terminology regarding these chemicals and areas of application. As a consequence, there are differences in expectations of these products, too.
In this paper, chemical systems are categorized as nonsealing and sealing. A standard testing procedure is suggested to help evaluate the performance of the different systems. Standardized testing should help the industry compare the performance of different systems under specific conditions. This paper will consider treatment techniques and operations to emphasize the importance of detailedjob design and operations planning. The paper ends with a summary of the economics involved in water and gas production. The method presented for determining a treatment's value can be used to evaluate the feasibility of water- or gas-control treatments.
Cyclic Steam Reservoir Model for Viscous Oil, Pressure Depleted Gravity Drainage Reservoirs
Authors: Jones Jeff 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
An improved cyclic steam reservoir model has been developed which allows the calculation of steam injection pressure and temperature as well as steam quality. In addition producing rates of oil and water are calculated with consideration given to cumulative effects of changing temperature, fluid levels, relative permeability, fluid viscosities, and fluid saturations. permeability, fluid viscosities, and fluid saturations. A comparison of calculated performance with field results of seven consecutive steam cycles in a well located in the Midway Sunset field in Western Kern County, California is presented. The calculated performance is in excellent agreement with field reports in virtually all areas.
The model is presented with simplified mathmatics by subsitituting empiracle equations for rigorous integral equations in several places. places

Introduction
The literature contains many reports of analytical and numerical reservoir models which may be used to calculate the response of a steam stimulation project.
Boberg and Lantz provide a very good method for tracing the temperature history of thermally stimulated wells. However, the method used to predict fluid production is limited to use in reservoirs with relatively light oil and high primary productivity.
Kuo, Shain, and Phocas do not address the performance of individual steam stimulation performance of individual steam stimulation cycles.
Seba and Perry address gravity drainage but also employ several limiting assumptions. These include constant hot zone radius and temperature and harmonic decline in oil production which may or may not match the decline in areas other than Yorba Linda.
Closmann, Ratliff and Truitt studied the effects of changing fluid saturations and crossflow in a cyclic well but simplified the heat loss mechanism and ignored gravity drainage.
Williamson, Drake and Chappelear treat the effects of transient relative fluid saturation and viscosity vs temperature in individual wells but the model is designed specifically for use in a numerical isothermal reservoir simulator.
In the above abreviated literature survey no provision was found for calculating injection pressure and the associated temperature. pressure and the associated temperature.
A Critical Review of Steamflood Mechanisms
Authors: Wu Ching H. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
A critical review of steamflood mechanisms is made based on published laboratory and field data. Qualitative and quantitative discussions are presented on the major steamflood mechanisms presented on the major steamflood mechanisms including steam drive and in-situ solvent drive; viscosity reduction and thermal permeability variation; and thermal permeability variation; and thermal expansion and gravity segregation. Interaction of these mechanisms is responsible for high steamflood displacement efficiency, enhanced oil production rate, and poor vertical steam conformance. A basic poor vertical steam conformance. A basic understanding of these mechanisms should assist petroleum engineers in the design, analysis, and evaluation of steamflood operation and mathematical simulation.

Introduction
Steamflooding is a proven secondary or tertiary method for recovering oil economically from some heavy oil reservoirs. It has potential applications as a secondary or tertiary method to recover light oils. Therefore, it is conceivable that steamflood mechanisms responsible for displacing oils or helping to displace oil from the reservoirs are of great interest and importance to the industry.
Steamflooding is a complex oil displacement process involving simultaneous heat, mass, and fluid transports. Although steamflood mechanisms associated with these complex transports may be well known to some people, reports on these mechanisms have been scattered in many publications over more than fifteen years and have not been readily available for most petroleum engineers. Willman, et al. reported experimental studies on the effect of some steamflood mechanisms, such as viscosity reduction, thermal expansion, and steam distillation, on the oil recovery. Johnson, et al. Quinones and Wu and Brown reported steam distillation of crude oils in porous media. Farouq Ali and Alikhan and Farouq Ali reported the effect of solvent slug on the oil recovery by steam and hot-water floods. Gates and Ramey, Dingley, and Braden presented the thermal viscosity reduction of some crude oils. Several articles reported the temperature effects on the oil-water relative permeabilities and on the absolute permeability.
Critical Cuttings Transport Velocity in Inclined Annulus: Experimental Studies and Numerical Simulation
Authors: Masuda Y. , Doan Q. , Oguztoreli M. , Naganawa S. , Yonezawa T. , Kobayashi A. , Kamp A. 
Published: December 2007

Abstract
In drilling horizontal wells and extended reach wells effective transport of drill cuttings is critical. Cuttings deposition and accumulation could lead to formation of deposit bed(s) inside the annulus, causing stuck drillpipe, eccentric borehole, poor penetration rate, etc. Experimental investigations reported in the literature previously focused on evaluation of cuttings transport performance in directional wells, as functions of mud flow rate, mud rheology, angle of inclination, pipe rotation, flow regime, etc. Empirical correlations were also developed for critical flow rate for different flow conditions.
In this study, both experimental investigation and numerical simulation were performed to determine the critical cuttings transport velocity in inclined annulus, for different flow conditions. Experiments were carried out in a flow-loop, using a novel data-acquisition-and-analysis system. The behavior of drill cuttings at both steady-state and unsteady-state flow conditions were recorded by a CCD video camera system. The captured images were then analyzed to obtain the velocity profile, the cross-sectional distribution, and average velocity of cuttings in annulus. Results from this experimental investigation were compared against those predicted by an unsteady-state cuttings transport numerical model developed in-house. The numerical model developed for the study allows for the interaction between the drill cuttings and drilling fluid, and follows broadly the two-layer model reported in the literature. It enabled the determination of pressure, fluid and cuttings velocity, fluid and cuttings concentration distributions inside the annulus at different times. The model was run using parameters similar to experimental conditions. Its results agree closely with experimental data for the critical flow rate for cuttings transport in inclined borehole, for the majority of cases.
A New Approach for Drill Bit Selection
Authors: Bilgesu H. I. , AL-Rashidi A. F. , Aminian K. , Ameri S. 
Published: December 2007

Abstract
Presented is a new methodology for selecting rotary drilling bits in an oil or gas well. Currently, bits are selected based on the performance of similar bits at offset wells. Parameters affecting a bit performance have a complex pattern. The relationship between formation properties, drilling fluid characteristics, bit design, and operational parameters in these patterns are not easily understood.
For a given field, studied were variables such as bit size, weight on bit, rotary speed, pump rate, drilled interval, and bit type. A three-layer artificial neural network was designed and trained with field data. This method incorporates computational intelligence to define the relationship between the variables. Further, it can be used to estimate other drilling parameters. The results indicate that the back propagation achitecture with two hidden slabs is the most effective neural network design for predicting the optimum bit type.
With the given data sets, this new model successfully predicted the bit types for several fields. For different data sets used in this study, the correlation coefficients for the predicted and field used bit types ranged between 0.857 and 0.975.
Two-Phase Relative Permeability Prediction Using a Linear Regression Model
Authors: Ibrahim M. N. Mohamad , Koederitz L. F. 
Published: December 2007

Abstract
In the absence of laboratory measured data or in the case when a more general representation of fluid flow in a reservoir is needed, empirical relative permeability correlations become useful. These correlations will also apply to simulation studies which require adjustments to the relative permeability values to account for grid effects. A linear regression model approach is employed to develop prediction equations for water-oil, gas-oil, gas-water, and gas-condensate relative permeability from experimental data. Use of the SPE CD-ROM has allowed a rapid and thorough data retrieval for this study; 416 sets of relative permeability data were obtained from published literature and various industry sources. Improved equations were developed for water-oil and gas-oil systems based on formation type and wettability. Additionally, general equations for gas-condensate and gas-water systems were formulated. Craig’s rule for determining the rock wettability has been modified to cover a wider range of relative permeability data currently available. Available data has increased significantly since the last published work in this area. The prediction equations are compared with previously published correlations where possible.
Optimizing Deliverability in Five Gas-Storage Reservoirs—Case Studies
Authors: Guoynes John , Squire Ken , Blauch Matt , Yeager Valerie , Yater John , Wallace Robert , Frame Russell , Clark Randall 
Published: December 2007

Abstract
Proper identification of damage mechanisms can improve stimulation techniques used in remediation of damaged gas-storage wells. Identifying damage mechanisms is only a beginning step in optimizing remediation. Determining the highest potential candidate wells and evaluating reservoir quality in the field can be just as crucial in optimizing a deliverability enhancement program. Historical data and reservoir/geological description analysis are required to properly rank candidates and design specific treatments to optimize deliverability potential. Once the diagnostic data and analysis are completed, an operator must begin the tedious process of applying the relevant data analysis to rank and validate the candidate wells’ potential and select one or more tailored treatment designs. Adequate well ranking is critical to ensure that APE dollars achieve maximum deliverability.
This paper illustrates case studies using a "Solution Team" a multidisciplined team process, in which over 75 wells were diagnosed and treated successfully. Rigorous damage-identification techniques and reservoir quality diagnostics were used in the five gas-storage reservoirs. Each case study produced damage-specific stimulation treatments based on the operator’s objectives to enhance existing deliverability. Follow-up evaluations were made at 1- and 2-year intervals to show how the team process that uses new, improved diagnostic practices can optimize deliverability.
In this study, damage mechanisms were identified with improved methods described in a previous Gas Research Institute (GRI) project. Damage in each well was quantified using welltest analysis and historical injection/withdrawal cycle performance matching. Log analysis, petrophysical data, geological data, wellbore imaging, and workover historical data were also gathered as treatment-design criteria. The deliverability improvement was quantified for each well using post-treatment diagnostics. The post-treatment evaluations were updated with 1- and 2-year follow-up evaluations. Each study incorporates several unique treatment options addressing a variety of damage mechanisms. Treatments were selected to produce the highest deliverability enhancement and maximize the operator’s return on investment.
Case Study 1 incorporates high-pressure jetting, tailored acidizing, and hydraulic fracturing techniques used in a deep high-permeability pressure-drive carbonate reservoir. Case Study 2 includes high-pressure jetting and damage-specific fluid treatments in two shallow water-drive clastic reservoirs. Case Study 3 incorporates hydraulic fracturing and high-pressure jetting of a shallow high-permeability pressure-drive clastic reservoir. Case Study 4 incorporates high-pressure jetting with foamed chemical treatments in a converted oil-carbonate reservoir.
Controlled Composition Seeded Growth Kinetics of Calcium Carbonate
Authors: Tomson M.B. , Nancollas G.H. , Kazmierczak T.F. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
A highly reproducible seeded crystal growth method is described for the study of calcium carbonate crystallization in which the solution composition is maintained constant by the potentiometrically controlled addition of reagents. This provides a system which closely models the conditions of precipitation and scale formation encountered in the precipitation and scale formation encountered in the field. Studies can be made over a range of supersaturation hitherto inaccessible by other methods. The experiments yield information about the mechanism of crystal growth and the influence of potential scale inhibitors upon the growth of the pure scale minerals and the formation of mixed scales.
The inhibitory effects of phosphate and a phosphonate both at micromolar and lower levels phosphonate both at micromolar and lower levels have been examined. Both markedly affect the calcium carbonate precipitation at concentrations as low as 10 molar.

Introduction
The precipitation and dissolution of carbonate minerals of divalent metal ions such as calcium carbonate (calcite and aragonite) and calcium magnesium carbonate (dolomite) are of considerable importance in a wide variety of fields such as limnology, oceanography and sedimentology. The crystal growth of calcium carbonate also has important applications in water purification technology. The concentration of calcium carbonate in many natural waters is equal to or greater than the saturation level and as a consequence, calcium carbonate precipitation and crystal growth takes place in water treatment and desalination place in water treatment and desalination facilities. The resulting scale formation on heat transfer surfaces during evaporative desalination may significantly increase the cost of potable water. Since the solubilities of the calcium carbonate polymorphs decrease with increasing temperature, polymorphs decrease with increasing temperature, the petroleum engineer also has to contend with carbonate scaling at the relatively high ambient temperatures down-hole.
Calcium carbonate has probably received the greatest attention in connection with its precipitation and dissolution in natural water systems. The reaction is very sensitive to the presence of magnesium ions which are normally present at relatively high concentrations. It has been reported that magnesium ions favor the formation of aragonite while markedly inhibiting the precipitation rate. precipitation rate.
Improvement of Waterflooding of a Heavy Crude Oil By Addition of Chemicals to the Injection Water
Authors: Okandan Ender 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
A laboratory study of applicability of chemical flooding to a heavy crude oil reservoir is presented. The contact angle behavior of oil-water-calcite system was investigated to see the effectiveness of several chemicals added to the injection water.
Displacement tests performed using two selected chemicals show an increase in recovery compared with plain waterflooding.

Introduction
In the literature, several surface-active agents are proposed and investigated for their effectiveness as chemical flooding agents. It has been observed that interfacial properties between crude oil and water, interactions between water, oil, and rock grain surfaces, and adsorption of surface-active chemicals are the prime factors that should be considered and controlled in the process.
It was reported half a century ago that effectiveness of waterflooding could be increased by the addition of chemicals that will cause low oil-water interfacial tensions. Until today, parameters like porosity, permeability, pore-size distribution, permeability, pore-size distribution, wettability conditions, interfacial properties, chemical selection, their adsorption, and chromatographic transport through porous media were investigated in order to understand how the mechanism by which chemical flooding will displace crude oil from pore spaces.
Comprehensive work has been done on the influence of interfacial tension on oil recovery after the 1950's. Among them, Reisberg and Doscher's work indicated oil recoveries reaching 90 and 100 percent with the use of surfactants that caused interfacial tensions less than 0.01 dyne/cm. Wagner and Leach's work indicates sigma less than 0.07 dyne/ cm causes increases in oil recovery in their system. Later, Taber showed theoretically and experimentally the dependence of recovery of residual oil on the Delta/L sigma factor. Recoveries reaching 100 percent were achieved when this ratio had much higher values than the critical value given as 2 to 5 Psi/ft dyne/cm for that system. It was recognized also in the same study that the contact angle, which is an indication of wetting conditions at solid-liquid interfaces, should be included in the ratio Delta P/L sigma. Different wetting conditions may exhibit different dependence of recovery on pressure gradient or flow rate.
Time Dependent Electrical Properties of Rock-Solution Systems
Authors: Weed H.C. , Piwinskii A.J. , Keller P.R. 
Published: December 2007

Abstract
The electrical conductivity of 25.4-mm diameter cylindrical cores of sedimentary and igneous rocks was measured at a frequency of 1 kHz under ambient conditions after saturation in tap water and in 0.1 M NaCl solution. Between measurements, each rock was stored in contact with its own separate solution that at the start of the experiment was either tap water or O. 1 M NaCl solution. Eighteen rocks having porosities between 0.07 and 42 percent were investigated; ten were sedimentary, eight were igneous. All solution conductivities were measured employing a dip cell. The time dependence of the conductivity was investigated as well as the range of validity of Archie's law. The formation factor and conductivity of rock specimens and their reacting solutions display time-dependent behavior up to 8,000 hours. The formation factor and electrical conductivity depend on the salinity of the pore fluid, the rock porosity and permeability, and the clay minerals present in the rock.

INTRODUCTION
We are currently investigating rock-solution interaction and its effect on electrical properties of rocks as a function of time, porosity, pore solution concentration, frequency, specimen aspect ratio, and Soxhlet extraction procedures. This work is part of a program to construct a laboratory data-base as an aid in the interpretation of field geoelectrical data. We1 previously observed that the formation factor and the electrical conductivity of the Pictured Cliffs sandstone (permeability range, 7Ã?10â?'4â?'4Ã?10â?'1 md; porosity range, 3.8 to 4.9 percent) display time-dependent behavior when the sandstone is saturated in tap water. Pretreatment of the rock by Soxhlet extraction lowers the formation factor, F, but does not significantly change the time dependence. Also, Duba et al.2 reported on the Ï? of cylindrical cores of Westerly granite; Nugget, St. Peter, and Kayenta sandstones; and Indiana limestone having aspect ratios (length/diameter) from 2.00 to 0.25. Before measurement, the cores were saturated in distilled water, tap water, and in 0.1 M NaCl solution. Aspect ratio affects least the conductivity of rocks saturated in 0.1 M NaCl; for these rocks a linear relationship exists between log Ï? and log Ï?, commonly termed 'Archie's law.' However, no simple correlation was found between log Ï? and log Ï? for rocks saturated in tap or distilled water. This paper is a progress report on the Ï? and F as a function of time up to 104 hours for 18 rocks saturated in tap water or in 0.1 M NaCl solution at 100 kPa pressure.