bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pore Size Distribution of Petroleum Reservoir Rocks
Authors: Burdine N.T. , Gournay L.S. , Reichertz P.P. 
Published: April 2012

Abstract
An investigation of equivalent pore entry radii in typical samples of petroleumreservoir rock and the pore volume associated with each value of pore entryradius has been made. Theoretical discussions together with experimentalprocedures for obtaining pore entry radii and the distribution of pore volumewith pore entry radii are presented. Experimental results on a number of coresamples, along with typical distribution curves, are shown. Data on the percent of the pore volume filled by mercury at a pressure of 1500 psi areincluded. The results of re-runs of samples, made possible by regenerativeapparatus, show the repeatability of the data and indicate the amount ofphysical change in the samples by mercury penetration. Theoretical equationsfor calculating permeability from pore size distribution data were derived andthe results of such calculations are compared with measured gas permeabilitydata. The effect of the shape, surface area, and weight of the sample on thepore size distribution of reservoir rocks was investigated experimentally.Mercury capillary pressure curves are compared with those obtained by theporous diaphragm method using gas to displace water.

Introduction
Standard core analysis techniques, in general, lead to quantities which arestatistical averages of the varying properties of the samples underexamination. Although such statistical information has real value in predictingthe gross performance of porous bodies, it fails to provide fundamentalinformation concerning the properties of the porous medium itself or anyprocesses which may be occurring in it. For example, a gas permeabilitymeasurement on a core sample is an indirect way of determining an average poreradius for that particular sample. Since there are many combinations of poreradii that will give the same radius, and, hence, the same permeability, noinformation is obtained on the pore size distribution. Furthermore, similarvalues in permeability do not imply similarity in other properties of a porousmedium. For instance, it is possible to have two core samples with identicalpermeability which would have different residual oil contents at the end of anair-oil drive, or even different amounts of interstitial water.
It has been recognized for some time by the petroleum industry that adetermination of pore size distribution for porous reservoir rocks offeredpromise of increased understanding of fundamental flow processes in the porousmatrix, and therefore of petroleum reservoir performance in general.
T.P. 2893
The SP Log in Shaly Sands
Authors: Doll H.G. 
Published: April 2012

Abstract
As a continuation of the earlier paper on the general subject of the SP log, amore complete analysis of certain features of the SP log in shaly sands isgiven. The pseudo-static SP in front of shaly sands is compared, on atheoretical basis, to the static SP in front of clean sands, as a function ofthe respective amount of shale and sand in the formation, and of the relativeresistivities of the shale, of the uncontaminated part of the sand, and of theinvaded zone of the sand.
As a conclusion, the advantage of using reasonably conductive mud in this caseis shown.
The discussion is illustrated by field examples.

Introduction
The discussion reported in the present paper is based on a theoreticalanalysis, and not on experiment. The field examples, joined to the text, areshown only as qualitative illustrations of the essential results of thisanalysis. Although the hypotheses made in the theoretical developments mayperhaps be somewhat improved, it seems, nevertheless, that the results obtainedaccount reasonably well for the actual phenomena, and give a fair approximationof their order of magnitude.
The paper contains a mathematical analysis of a tri-dimensional distribution ofpotentials and current lines, due to spontaneous electromotive forces arisingat the contact of shales and free electrolytes, as a function of the geometryand of the respective resistivities of the different media involved. It isassumed, although this hypothesis is not proven, that the emf's remain the sameeven if the shale occurs in very thin layers or in dispersed particles.
It has already been pointed out that, all other conditions being the same, thedeflection of the SP log in front of a shaly sand is smaller than opposite aclean sand. When the thickness and the conductivity of a clean sand are largeenough, the deflection of the SP log reaches a limiting value which is equal tothe "static SP" of the clean sand. It is generally convenient to takethe static SP of shale as the reference value or "base line." As aconsequence, and for the sake of abbreviation, the expression, "static SPof a clean sand," is often used to designate the difference between thestatic SP of that sand and that of the shales, which difference is a measure ofthe total electromotive forces involved in the chain mud sand-shale.
T.P. 2912
Analysis of Fractured Limestone Cores
Authors: Kelton Frank C. 
Published: April 2012

Abstract
A method is outlined for the analysis of large cores, developed primarily forthe purpose of obtaining reliable data on fractured or vugularlimestones.
Porosity and fluid saturations are determined by a modified Dean-Starkextraction after initially bringing the samples to 100 per cent liquidsaturation by a vacuum-pressure method. Horizontal permeabilities on the wholesamples are determined in two directions, parallel and perpendicular to thedirection of principal fracturing.
Results are presented for various types of formations. A comparison is madebetween data obtained by this special method and the method of conventionalanalysis, and discussion is given of the relative advantages and limitations ofeach. In view of this comparison a modified method for the analysis offractured and vugular formations is proposed, which method retains theadvantages of the previously outlined techniques but gives promise of speedingup the analysis.

Introduction
For many years the greater part of the production in the Permian Basin was fromformations of Permian and Pennsylvanian age. While production from theseformations is still the predominant production, deeper prospecting has broughtto light older formations with oil productive characteristics. Attempts to corethese deeper horizons were at first usually characterized by poor recovery. Theold rule of thumb, "good core recovery - poor well" was originated andremained in effect until recently. With the advent of diamond coring and theincreased efficiency in drilling and coring operations, the old adage has lostits significance. Formations of Devonian, Silurian and Ordovician ages weresuccessfully cored with varying degrees of recovery. The cores thus obtainedwere surprising and in some cases disappointing. Good recovery from theseformations led to speculation as to the feasibility of analysis and the meaningof data obtained from conventional analysis. Commercial laboratories wereengaged to analyze these cores, and their results indicated that data obtainedby conventional methods would be of little value. From visual inspection it wasapparent that in many cases the effective porosity for storage of hydrocarbons, and permeability, were contained largely in fractures and solution cavitiesrather than in the primary crystalline structure of the formation. In othercases the solution cavities augmented the effective porosity of the primarycrystalline structure, or fractures enhanced the permeability of the latter sothat the formation might respond favorably to acidization and becomecommercially productive. Since the spacing of the cavities and fractures wasoften comparable to the core diameter, it was evident that the entire coreshould be analyzed instead of small fragments.
T.P. 2913
Vapor-Liquid Equilibrium Data on the System Natural Gas-Water-Triethylene Glycol at Various Temperatures and Pressures
Authors: Porter Joe A. , Reid Laurance S. 
Published: April 2012

Gas dehydration plays an important part in the production of natural gas.Effective dehydration prevents formation of gas hydrates and the accumulationof water in transmission systems, insuring uninterrupted gas deliveries atmaximum efficiency under the most adverse weather conditions. At the presenttime, most gas companies require a maximum water vapor content of seven lb permillion standard cu ft of gas, so that virtually all gas tendered for sale mustbe dehydrated to meet this specification.
For a number of years it has been common practice to produce gas and gather itat a common point for dehydration prior to discharge into the transmissionsystem. However, higher transmission line pressures, long gathering lines andrelatively low ground temperatures have made it necessary to dehydrate gas at, or near, individual wells in order to gather gas from a number of newlydeveloped fields without unusual difficulty. Where gas has been dehydrated atpressures ranging from 300 to 800 psi in the past, future trends indicate thatthese processes may be operated at pressures as high as 2,000 psi.
Economics of gas dehydration are of great importance, particularly wherefacilities must be provided to process relatively small quantities of gas, suchas the production from an individual well. Although the adsorption of watervapor from gas on a granular sorbent material such as activated bauxite, activated alumina, or one of the alumina-silica gels is highly effective andproduces virtually "bone dry" gas, the cost of a small unit of thistype is substantially greater than that of an absorption process which, throughproper selection of the absorbing liquid, will dehydrate the gas sufficientlyto meet pipe line specifications. For this reason, a great deal of emphasis hasbeen placed on the development of small, inexpensive dehydration units and thesearch for more effective absorbent liquids has been intensified.
T.P. 2848
Volumetric Behavior of Oil and Gas From a Louisiana Field I
Authors: Reamer H.H. , Sage B.H. 
Published: April 2012

Abstract
An experimental investigation was conducted upon five different pairedsamples of oil and gas from a field in Louisiana. The study, with each pair ofsamples, included the measurement of the formation volume and the volume of theliquid phase for three mixtures of the oil and gas. The gas-oil ratio variedfrom approximately 200 to over 40,000 cu ft per bbl and measurements were madeat temperatures between 40' and 250'F. The gravity of the tank oil for the fivesamples under investigation varied between 38.0? and 55.8? API.
The composition of the oil and gas samples and their mixtures is submitted intabular form. A number of diagrams depicting the effect of temperature andgas-oil ratio upon retrograde dew-point pressure are presented.

Introduction
During the past two decades a fairly large number of investigations were madeof the volumetric behavior of naturally occurring hydrocarbon mixtures. Theearlier work of Beecher and Parkhurst and a more recent report on samples fromDominguez Field are typical of research of this nature. Such studies have beenused in estimating the volumetric behavior of fluids in producing fields otherthan those from which samples were taken. Progress has been made in correlatingthe influence of pressure, temperature, and composition upon the specific andformation volume of hydrocarbon mixtures of relatively low gas-oil ratios, butattempts to extend this correlation to higher ratios have not been particularlysuccessful. The influence of composition upon the volumetric behavior of suchsystems cannot be simply related to a single parameter such as gas-oil ratio.In order to aid in the extension of the correlation, of the volumetric behaviorof mixtures of oil and gas to higher ratios, a rather complete study was madeof five different pairs of samples from a Louisiana field. The complexity ofthe influence of composition upon the volumetric and phase behavior of suchsystems in the regions of retrograde condensation was indicated by earlierwork, and it is doubtful if simple correlations can be established in theseregions with the information currently available. The terminology employed inthis paper is identical to that utilized earlier.
T.P. 2950
The Kobe Porosimeter and the Oil Well Research Porosimeter
Authors: Beeson Carrol M. 
Published: April 2012

Abstract
Reasons are given for using a Boyle's-law porosimeter in conducting coreanalysis for either routine or research purposes. Among other things, it ispointed out that such a porosimeter permits the measurement of all basicproperties on the same sample, thereby eliminating the sources of errorinherent in the use of adjacent samples. References are made to investigationsof gas adsorption on various porous materials, to show that the use of heliumin Boyle's-law porosimeters reduces to negligible proportions the error due tothe adsorption or desorption of the operating gas.
Two Boyle's-law instruments are described, which permit accurate and rapidmeasurements of porosity. Schematic sketches and explanations are included, along with derivations of equations required in performing precisedeterminations.
Summaries of data obtained during calibration are tabulated and analyses of thedata are presented as indications of the precision and accuracy of each device. Comparisons are also shown for measurements made with each of the instrumentson the same test pieces and cores.

Introduction
An accurate porosimeter, operating on the principle of Boyle's law, is ofconsiderable value in the analysis of cores for either routine or researchpurposes. This is due primarily to the fact that the measurement of porositywith such an instrument leaves the sample free of' contamination by anyliquid.
When used in conjunction with an extraction apparatus for determining oil andwater saturations, a Boyle's-law porosimeter permits the measurement of allbasic properties on the same sample. This eliminates the sources of errorinherent in the use of adjacent samples, or the necessity of determiningporosity after all other properties have been obtained.
Large errors may result from combining measurements made on adjacent samples inorder to obtain a single property. This type of error is definitely involvedwhen oil and water are measured with one sample and the pore volume is measuredwith an adjacent one. Furthermore, the source of error would be present to someextent, even if the analyst could choose the samples so they were trulyadjacent from a geological standpoint.
T.P. 2953
Relative Productivity of Perforated Casing - II
Authors: Howard Robert A. , Watson Marsh S. 
Published: April 2012

Abstract
The effect of depth of formation penetration by casing perforations has beenstudied by means of an electrolytic model. It is found that the relativeproductivity of perforated casing is profoundly affected by the depth to whichthe formation is penetrated. The first in. of penetration is of especialimportance. A scaling equation which was shown to agree with experimentalresults at zero penetration is used to calculate the relative productivity of ascaled down casing with scaled down perforations.

Introduction
In an earlier paper the authors showed that the point sink representation ofcasing perforations is inadequate. It was pointed out at that time that whilethe electrolytic model results were a marked improvement over point-sinkcalculations, they still left a great deal to be desired in that theelectrolytic model represented a case not realizable in practice, namely, aclean hole through the casing but undisturbed formation on the other side ofthe casing. Obviously, to be effective, the perforation must penetrate a finitedistance into the producing formation. It was the purpose of the presentinvestigation to find how the relative productivity of perforated casing varieswith depth of penetration.
The term "depth of penetration" as used in this paper refers to thedistance which the perforation penetrates the producing formation. The amountof casing and cement penetrated is not taken into account, a fact which isdiscussed more fully later. The "casing radius," therefore, is to beinterpreted as the radius of the boundary between cement and formation wall, incases where the casing is not in contact with the formation wall.

Apparatus
The electrolytic model experimental setup was identical with that describedin the previous paper except that the platinum electrodes were now allowed toproject from the lucite cylinder by varying amounts. When fewer than eightelectrodes were used, the unused ones were covered with a coat of insulatingmaterial to minimize disturbances to the current flow-lines.
T.P. 2933
High Pressure Water Injection for Maintaining Reservoir Pressures, New Hope Field, Franklin County, Texas
Authors: Trube Albert S. , DeWitt Sam N. 
Published: April 2012

Abstract
This paper presents a discussion of the pressure maintenance operations whichwere begun in the New Hope Field, Franklin County, Texas, in 1944. The projecthas required the injection of extraneous waters at depths from 7,300 to 8,00'Ft with intake well-head pressures up to 4,000 psi in three differentreservoirs - the Bacon, Hill, and Pittsburg.
Records of oil and water production, water injection and the GOR have been keptfor each reservoir and reservoir pressures were taken at regular intervals.These data indicate that the Bacon Reservoir had no apparent water encroachmentup to the time of water injection. However, the Pittsburg and Hill reservoirshad some natural water influx but not sufficient to prevent pressures fromdeclining below the bubble point. The Bacon and Hill reservoirs respondedalmost immediately to water injection, while the Pittsburg, which is the leastpermeable, has shown good pressure response only since August, 1948.
The principle objective of the project has been to increase ultimate recovery.Success of the project to date also has resulted in reduced lifting costs.Estimates based on the initial water breakthrough patterns indicate that theprimary objective of substantial additional recovery will be accomplished, andthere is a possibility that the original estimates of oil recovery withpressure maintenance will be exceeded.

Introduction
This pressure maintenance project was one of the earliest primary pressuremaintenance programs to be attempted on a multiple zone field. There are threeproducing reservoirs into which water is being injected for the purpose ofmaintaining pressure and increasing the ultimate recovery from each. This paperis limited in scope to all account of the development of the project, thepressure production relationship prior to the injection of water and the effectof water injection on the producing reservoirs. Also discussed are the natureof the injection system and the indicated results on initial waterbreak-through in the Bacon Reservoir.
T.P. 2939
Attainment of Connate Water in Long Cores by Dynamic Displacement
Authors: Slobod Robert L. 
Published: April 2012

Abstract
In much of the work reported in the literature on long cores, true connatewater values probably have not been obtained because of insufficient flow ofoil to attain equilibrium. A satisfactory method for establishing connate waterin long cores has been developed in which oil flow is maintained until noadditional water is displaced.

Introduction
Long cores have been used by several investigators in an effort to evaluate theefficiency of oil recovery for various producing schemes. The effects of manyvariables such as rate of displacement, pressure drop, volume of displacingmedium, gas-oil ratio, interfacial tension, and others have been investigated, and the merits of gas drive have been compared with water drive. In the olderexperiments no connate water was used, but in the more recent studies thephilosophy of the experiment calls for a core containing oil and connate water(irreducible water) as the starting point of the experiment. The methodgenerally used to establish this condition in long cores involves dynamicdisplacement wherein one or more phases are forced through the core, flow beingmaintained at a constant rate or at a constant pressure until a steady state isreached wherein there is no change of saturation with time. It is one purposeof this paper to point out that in much of the work reported in the literaturetrue connate water values probably have not been obtained. The reason for thisfailure is pointed out, and a method for obtaining more reliable connate watervalues on long cores is presented. It is impossible at this time to completelyevaluate the effect on the conclusions in the earlier papers resulting from thefailure to obtain true connate water in the long cores, but some data arepresented which indicate that serious errors may be present in many cases.
T.N. 55
Lime Content of Drilling Mud-Calculation Method
Authors: Nelson M.D. , Watkins T.E. 
Published: April 2012

A method of determining the lime content of drilling muds proposed by Battleand Chaney has been examined both in the Field Research Laboratories ofMagnolia Petroleum Co. and in field drilling operations. This proposedanalytical method is condensed as follows: Titrate one ml of mud and one ml ofmud filtrate, each with 0.02 N H2SO4 to the end point with phenolphthalein. Thevolume of acid in ml required for the mud titration is recorded as Pm and thatof the mud filtrate titration as Pf.
The analytical procedure outlined by Battle and Chaney was found to be quitesatisfactory when reasonable precautions are used in mud sampling technique.Calculation of lime concentration by the method proposed in the abovepublication, however, has given values that varied as much as 100 per cent fromthe known lime content, for muds of either high or low solidsconcentration.
By use of a formula, based on chemical equivalents of acid required fortitration, both laboratory and field data have been satisfactorily correlatedwith the known amounts of lime present in the muds. In this formula acorrection, FL, or volume fraction of liquid in the mud, is made for the solidcontent of the mud. Pm and Pf have the same significance as in the Battle andChaney equation. Table I shows typical data employing both formulas incalculating the lime content of various lime muds.
This suggested procedure ignores lime which is in solution in the mud. Thesolubility of lime in water, normally about 0.5 lb per bbl, is greatlydecreased by the addition of caustic soda, and, in a lime mud, it is probablethat the concentration of dissolved lime is of the order of 0.1 lb per bbl.Such an amount of lime can be ignored, since it is within the range of accuracyof the method.
T.N. 58