bluuebunny/crossref_metadata_2025_split huggingface dataset:
Low Temperature Dehydration of Natural Gas
Authors: Records Louis R. , Seely Dwight H. 
Published: April 2012

Abstract
A process for low-temperature dehydration of natural gas utilizingJoule-Thomson effect in expansion through a throttling orifice has been testedin a full-scale field installation. The results of these tests are presented inthe form of performance curves from which the process may be easilyevaluated.
The effect of separation temperature on condensate recovery from the processis also shown.

Introduction
The transportation of natural gas from producing well to the consumer hasalways encountered the problem of hydrate prevention. This problem has becomeincreasingly important in the past ten years due to the rapid increase inproduced gas volumes, production pressures, transportation pressures anddistance from producing wells to consumer.
Natural gas, as normally produced from gas or gas-condensate wells, issaturated with water vapor at well-head conditions of temperature and pressure.The solution of the hydrate problem requires but one basic process -dehydration of the gas to a water content which will result in a waterdew-point below the minimum temperature to be encountered from the producingwell to the point of consumption.
Much of the recent development of gas and gas-condensate reserves in theGulf Coast Area has been in locations which are accessible only by water. Highwell-head pressures, pipeline construction and maintenance costs and thedesirability of final central gas-condensate separation facilities havestimulated the development of dehydration equipment which can be installed ateach well and which will permit hydrate-free transportation of both gas andcondensate in the same line to central facilities.
There are four types of natural gas dehydration processes now used:Adsorptive processes.Absorptive processes.Chemical reaction processes.Refrigeration processes.
The first three of these processes are indirect in that they require use ofadsorbents, absorbents or reactive chemicals. These materials requireregeneration and part of the total gas stream is consumed in the regenerativeprocess. Indirect processes have a wide range of flexibility as defined byallowable operating pressure and temperature, but most are not easily adaptedto automatic operation.
The refrigeration process described in this paper was designed forinstallation at the producing well-head. It requires no regenerative cycle andwith normal well-head temperatures no external source of heat. The flexibilityof this process is limited only by the pressure drop which may be allowedbetween well-head and transportation line.
T.P. 3022
Carrying Capacity of Drilling Muds
Authors: Williams C.E. , Bruce G.H. 
Published: April 2012

Abstract
The trend toward deeper drilling, together with the attendant increase inpower requirements for circulation of the drilling fluid, has emphasized theneed for a critical examination of the factors affecting the removal of bitcuttings from the hole by the drilling fluid. The ability of drilling fluids tolift cuttings is called their carrying capacity.
A series of laboratory and field experiments has been conducted to determinethe minimum annular velocity necessary to remove cuttings, and to investigatethe effects of properties of drilling fluids on their carrying capacities.
Consideration of the results of these experiments led to the followingconclusions:Turbulent flow in the well annulus is most desirable from the standpointof cutting removal.Low viscosity and low gel are advantageous in removing cuttings.Increase in mud weight is effective in increasing carrying capacity.The carrying capacity is higher when the pipe is rotated than when it isnot.If turbulent flow can be maintained, an annular velocity slightly higherthan the slip velocity of the largest cuttings to be transported should keepthe bore hole clean. This implies velocities of 100 to 125 ft per minute ratherthan the presently used 175 to 225 ft per minute.

Introduction

Power Savings by Reduction of Annular Velocities
A large portion of the power expended in drilling operations is consumed incirculating the drilling fluid. An important factor in establishing the rate ofmud circulation is the minimum velocity in the annulus necessary to remove bitcuttings. Empirically, it has been found that average annular mud velocities ofabout 200'Ft per minute will remove cuttings. It was not definitely known, however, whether annular velocities of about 200'Ft per minute were just abovethe minimum necessary to remove cuttings, or whether such velocities could bematerially reduced without sacrifice of the ability of the mud to removecuttings. It is apparent that if annular velocities could be reduced withoutimpairment of cutting removal, a considerable saving in power requirementswould result.
T.P. 3026
Effect of Free Gas Saturation on Oil Recovery by Water Flooding
Authors: Holmgren C.R. , Morse R.A. 
Published: April 2012

Abstract
The production of oil by water flooding can be substantially increased bythe maintenance of free gas saturation in the reservoir during the floodingoperation. This effect is accomplished by the alteration of oil relativepermeability characteristics and the occupation by gas of pore space that wouldotherwise be filled with residual oil. The amount of reduction in residual oilcan be calculated from appropriate water-oil relative permeabilitycharacteristics.
This paper presents experimental data in support of the foregoingconclusions and an example of the calculations. The microscopic pore saturationconcepts of the mechanism are discussed. A method of practical application tofield floods is presented together with discussion of certainlimitations.

Introduction
The presence of free gas has been reported by a number of investigators tosignificantly affect the oil recovery which can be obtained from sandstone flowsystems by water flooding. The effect of gas, noted in every instance, has beento cause lower residual oil saturations than could be obtained by waterflooding the same systems in the absence of free gas. The degree of improvementin recovery has been observed to vary widely, depending on the systems used andthe conditions of the tests. The increased oil recovery obtained because of thepresence of gas during a water flood has been variously attributed to changesin physical characteristics of the oil, selective plugging action of the gas, inclusion of oil mist in the free gas phase, and the additional sweeping ordriving action of the free gas.
All but the first of these suggestions imply changes in the displacementmechanism. The change in viscosity and interfacial tension of the oil phase, within the pressure range used for all the experimental work, is certainly notsufficient to account for the differences in residual oil saturation notedunless there is a drastic change in the displacement process.
One other effect which logically seems capable of causing differences inresidual oil saturation of the magnitude noted in the experimental work is thatof simple replacement. In a water-wet system containing oil, water, and gas, itis to be expected that the gas will exist inside the oil.
T.P. 3055
Further Developments in the Laboratory Determination of Relative Permeability
Authors: Caudle B.H. , Slobod R.L. , Brownscombe E.R. 
Published: April 2012

Abstract
An earlier publication has discussed three methods for obtaining relativepermeability data on small core samples and the apparatus and technique for thecapillary pressure displacement method. This paper describes the apparatus andtechnique for the solution gas and the dynamic displacement methods andpresents a routine procedure for obtaining oil-gas and water-oil relativepermeability data.
Theoretical and experimental considerations are presented to show that theend effect commonly associated with the dynamic flow mechanism is extremelysmall where constant rates are employed in the flowing phase. An effect of flowrate on relative permeabilities obtained by the dynamic system is found onlywhen gas is one of the flowing phases and this effect is ascribed to a form ofchanneling in the capillary system.
The apparatus and procedures used to obtain relative permeability data withthree phases flowing are described and some preliminary results of the use ofthis method are shown.

Introduction
In a previous publication from this laboratory there appeared a briefdiscussion of the concepts behind three basic methods for obtaining relativepermeability data. These three methods were called the capillary pressuredisplacement method, the solution gas displacement method, and the dynamicdisplacement method - the names being suggestive of the type of process usedfor obtaining the desired saturation prior to making the permeabilitymeasurements. In the same publication, the apparatus and technique for thecapillary pressure displacement method were described and some typical resultsobtained by this method were presented. This paper will present:The routine procedure used to obtain permeability data on small coresamples flowing;The experimental techniques for the solution gas and dynamic displacementmethods for obtaining relative permeability data;The results of some studies on the mechanism of fluid flow throughconsolidated porous media; and,The preliminary results on the determination of relative permeability for asystem in which three phases are flowing.
T.P. 3056
Steady Flow of Two-Phase Single-Component Fluids Through Porous Media
Authors: Miller Frank G. 
Published: April 2012

Abstract
This report presents developments of fundamental equations for describingthe flow and thermodynamic behavior of two-phase single-component fluids movingunder steady conditions through porous media. Many of the theoreticalconsiderations upon which these equations are premised have received little orno attention in oil-reservoir fluid-flow research. The significance of theunderlying flow theory in oil-producing operations is indicated.
In particular, the theoretical analysis pertains to the steady, adiabatic, macroscopically linear, two-phase flow of a single-component fluid through ahorizontal column of porous medium. It is considered that the test fluid entersthe upstream end of the column while entirely in the liquid state, movesdownstream an appreciable distance, begins to vaporize, and then moves throughthe remainder of the column as a gas-liquid mixture. The problem posed is tofind the total weight rate of flow and the pressure distribution along thecolumn for a given inlet pressure and temperature, a given exit pressure ortemperature and given characteristics of the test fluid and porous medium.
In developing the theory, gas-liquid interfacial phenomena are treated, phase equilibrium is assumed and previous theoretical work of otherinvestigators of the problem is modified.
Laboratory experiments performed with specially designed apparatus, in whichpropane is used as the test fluid, substantiate the theory. The apparatus, materials and experimental procedure are described. Comparative experimentaland theoretical results are presented and discussed.
It is believed that the research findings contributed in this paper shouldnot only lead to a better understanding of oil-reservoir behavior, but alsoshould be suggestive in regard to future research in this field of study.

Introduction
In recent years much time and effort has been consumed in both theoreticaland experimental studies of the static and dynamic behavior of oil-reservoirfluids in porous rocks. Although lack of sufficient basic oil-field data, principally concerning the properties and characteristics of reservoir rocksand fluids, largely precludes quantitative application of research results tooil-field problems, qualitative application has become common practice. Ineffect, oil-reservoir engineering research is serving as a firm foundation foroil-field development and production practices leading to increased economicrecoveries of petroleum. This province of research, however, still poses manyperplexing problems.
T.P. 3079
Phase Equilibria in Hydrocarbon-Water Systems III - The Solubility of Methane in Water at Pressures to 10,000 PSIA
Authors: Culberson O.L. , McKetta J.J. 
Published: April 2012

Abstract
Experimental and smoothed data are presented for the solubility of methanein water for temperature, of 77, 100, 160, 220, 280, and 340'F at pressures to10,000 psia.
The minimum solubility phenomenon exists within this temperature range topressures of 10,000 psia.

Introduction
The study of hydrocarbon-water systems has been extended to thedetermination of the solubility of methane in water at pressures to 10,000psia. The experimental apparatus and the technique, are the same as thatpreviously reported.
In the determination of the solubility of methane in water, only two phaseswere present at temperatures between 100 and 340'F, these being the vapor phaseand the water-rich liquid phase. The determinations involved the agitation ofmethane and water in an equilibrium cell, withdrawal of a sample from theliquid phase, and the analysis of the sample. The experimental valuesdetermined in this manner are presented in Table I and in Fig. 1.
Since experimental and analytical techniques have improved since the initialexperiments with this equipment, it was decided to repeat the 77?F isothermdeterminations. Fig. 1 shows that the individual results for this isotherm aremuch more nearly consistent than the data previously reported.
T.P. 3082
Surface Indicating Pressure, Temperature and Flow Equipment
Authors: Riordan M.B. 
Published: April 2012

Abstract
A surface indicating pressure, temperature and flow instrument that employsvariable frequency sensing elements has proved useful in evaluating flowcharacteristics of wells. Relative productivity of individual oil and gas sandsin a given well can be analyzed at several back pressures.
The variable frequency sensing elements are an improvement in sensitivityand accuracy and make possible observation of temperature and pressurevariations that have not been possible heretofore. The surface indicatingfeature results in a more direct approach to solving problems and eliminatesmany assumptions.
All three subsurface factors are evaluated, and correlation between themresults in a direct means of analyzing reservoir and well conditions.
Surveys have been used to evaluate well performance, locate gas entry inhigh ratio wells and to investigate gas injection and water floodingconditions.

Introduction
In a flowing well that is open to a multiple number of producing sands withvarying characteristics, it is valuable to know which sands are producing fluidat a given back pressure and in what relative quantity. Core studies couldqualify an interval as productive, and reserves would be computed on thisbasis. Unless the well is produced so that the interval does contribute, irreparable damage to the interval can occur. It is generally accepted that theoptimum condition of production of oil in an oil well will be, if the objectiveis to produce the largest amount of oil at the least cost, to produce oil atsuch rates of flow that the decline of production and the intrusion of edgewater should be uniform as between all portions of the producing horizonsproducing into the well. An indirect approach to this problem does not alwaysresult in a timely practical answer. To insure a correct answer, the conditionshould be measured as directly as possible, while the well is being produced.The PTF equipment was developed with this objective. Measurements of allvariable factors that can be associated with fluid movement, to a high degreeof dependability and accuracy, was a design requirement.
Initial field use has indicated that sufficient data can be obtained withthe instrument to answer the questioned conditions in a reasonable length oftime and at a reasonable cost.
A description of the instrument, the principals of operation, and the fieldexperience are discussed herein.
T.P. 3080
An Experimental and Theoretical Investigation of Gravity Drainage Performance
Authors: Terwilliger P.L. , Wilsey L.E. , Hall Howard N. , Bridges P.M. , Morse R.A. 
Published: April 2012

Abstract
Theoretical and experimental investigations of a constant pressure gravitydrainage system are reported. Experimental data are presented to show thatrecovery to gas breakthrough by gravity drainage is inversely proportional torate. The gravity drainage reference rate, which is numerically equal to theso-called "maximum theoretical rate of gravity drainage" is shown tohave no particular significance from a recovery standpoint. Before this ratecan be used as a basis of comparison for recoveries, it is necessary that therelative permeability and capillary pressure characteristics and displacingfluid viscosities be identical for the systems compared.
A method is presented by which accurate prediction of the performance of agravity drainage system can be made. Close agreement between experimental andcalculated drainage performance shows that steady state relative permeabilityand static capillary pressure data can be used to describe fluid displacementbehavior. The very wide range of liquid recoveries before gas breakthroughwhich result from production rate variation alone demonstrates the importanceof this factor in planning depletion of a gravity drainage reservoir.Calculated results are presented which show that little additional recovery canbe expected from a high pressure gravity drainage system between the times ofgas breakthrough and attainment of such high gas/liquid ratios as to makefurther pressure maintenance impractical.

Introduction
It has been recognized for some time that gravity forces play an importantpart in the recovery of oil from some types of reservoirs. Field experience hasshown that under certain conditions, gravity drainage can result in very highoil recoveries. Qualitative reasoning has led most engineers to the generalconclusions that:Where gravity drainage is important, the reservoir pressure should bemaintained by gas injection at the crest of the structure to prevent shrinkageof the oil in place and to keep a low viscosity so the oil can drain at thefastest possible rate.Recovery by gravity drainage is rate sensitive.
A survey of the literature indicates that while considerable work has beendone on the effects of gravity in oil production problems, no satisfactorymethod of calculating the performance of gravity drainage reservoirs has beenreported. In the absence of any proven method of calculating reservoirperformance, the level at which pressure should be maintained and the rate ofproduction for most efficient operation has been open to debate.
T.P. 3199
Porosity-Measurement Comparisons by Five Laboratories
Authors: Dotson B.J. , Slobod R.L. , McCreery P.N. , Spurlock James W. 
Published: April 2012

Abstract
A core sample porosity-check program is described. A number of laboratoriesparticipated in the investigation, which comprised measuring the porosities often selected natural and synthetic core samples. Each laboratory employed itsown method (or methods) of measurement. These included Boyle's Law, water-saturation, and organic liquid-saturation methods. Brief descriptions ofeach method employed are given. In general, the measured values of porositywere in reasonably good agreement. The average deviation of porosity from themean or average values for the group of samples was ?0.5 porosity per cent. Theresults of these measurements are compiled and presented in graphical form.

Introduction
The total bulk volume of a porous sample is derived from the sum of twovolumes, the void or pore volume and the solid or grain volume. The porosityfraction of the sample is defined as the ratio of the void volume to the bulkvolume. Multiplication of this ratio by 100 converts it to per centporosity.
Distinction is made here between total porosity and effective porosity. Theformer includes all void space, both interconnected and isolated, while thelatter includes only those voids which are interconnected. This investigationdeals only with the effective porosity.
Numerous cases had been noticed in which there appeared to be appreciablediscrepancies in the results of porosity determinations on core samples.Differences of as much as 10 to 15 porosity per cent had been reported fromdifferent sources for the same sample.
T.P. 3231
The Calculation of Water Resistivities From Chemical Analyses
Authors: Dunlap H.F. , Hawthorne R.R. 
Published: April 2012

Abstract
A method of calculating formation water resistivities from chemical analysesis presented which is somewhat faster and more accurate than previouslydescribed methods. For 26 formation water samples taken from wells in the TexasGulf Coast, the average deviation of calculated from measured waterresistivities was 3.3 per cent, with an average bias of + 1.1 per cent in thecalculated values. This compares with average deviations of 4.6 per cent and7.8 per cent, with corresponding average biases of +3.2 per cent and -6.3 percent, for the two methods previously described in the literature. All threemethods are sufficiently accurate for most purposes; the main advantage of themethod presented is its speed and convenience.

Discussion
It is frequently desirable to calculate the formation water resistivity fromthe chemical analysis of the water, as for example, in electric loginterpretation. Two methods have previously been given in the literature foraccomplishing this. Both methods require that the chemical analysis be given inthe Palmer system, as primary and secondary alkalinity and salinity. Thisconversion of the values of the ppm of the various ions to primary andsecondary salinity and alkalinity is time consuming, and many laboratoriesreport only the concentrations of the various ions in parts per million.However, all laboratories report the individual ionic concentrations, whetheror not the Palmer system of reporting is also used. Hence it was thought that amethod that would permit resistivity calculations directly from these datawould be useful.
In the method developed, the various ions reported in the chemical analysisare converted to an equivalent amount of NaCl. The sum of the variouscontributions to the NaCl (actual or equivalent) can then be used inconjunction with a plot of NaCl concentration versus resistivity to obtain theresistivity of the solution in question.
T.N. 67
Theoretical Note on Linear Absorption Methods of Determination of Fluid Saturation in Porous Media
Authors: Lipson Leonard B. 
Published: April 2012

Boyer, Morgan and Muskat, with improvements by Morgan, McDowell, and Doty, and Laird and Putnam, have described a scheme for the determination of fluidsaturation porous media by measuring the x-ray linear absorbing power ofparticular fluids in the media. This method is one of several which depend onthe linear absorbing power of the fluids in the porous medium. Other examplesof linear absorption methods involve measurement of dielectric constant, gammaray absorption, and ultrasonic attenuation. It is the purpose of this note todemonstrate by theoretical considerations that the absorption versus saturationcurve for a linear absorption method is not necessarily a single valuedfunction of the saturation. Such non-unique behavior must be considered andevaluated before suitable saturation determinations can be made by a linearabsorption method.
To illustrate the discussion, examples will be given only for the simplestcases of combinations of two different dielectrics. The dielectric constantmethod was chosen for illustration because it was thought to demonstrate mostgraphically the point in question.
According to Argue and Maass, the resultant dielectric constant of acombination of two different dielectrics depends on the orientation of thedielectrics in the electric field of the test condenser used to measure thedielectric constant. One case involves alternate slabs of dielectrics E1 and E2perpendicular to the electric field of the test condenser, as shown in Fig.1A.
T.N. 83