bluuebunny/crossref_metadata_2025_split huggingface dataset:
Estimation of Reserves and Water Drive From Pressure and Production History
Authors: Brownscombe E.R. , Collins Francis 
Published: April 2012

Abstract
A study has been made of the material balance-fluid flow method ofestimating reserves and degree of water drive from pressure and productionhistory data. By considering the effect of random pressure errors it is shownthat in a particular example a standard deviation of three and one-half poundsin each of ten pressure surveys permits the determination of the reserves witha standard deviation of 8 per cent and the water drive with a standarddeviation of 15 per cent, assuming that certain basic geologic data arecorrect. It is believed that this method of estimating reserves and water driveis useful and reliable in a number of cases. The method is particularlyvaluable when reservoir pressure data are accurate within a very few pounds, but may also be applied with less accurate pressure data if a relatively largereservoir pressure decline occurs early in the life of the field, as forexample in an undersaturated oil field.

Introduction
A knowledge of the magnitude of reserves and degree of water drive presentin any newly discovered petroleum reservoir is necessary to early applicationof proper production practices. A number of investigators have contributed tomethods of relating reserves, degree of water drive, and production andpressure history. Three types of problems of increasing complexity may bementioned. If a reservoir is known to have no water drive, and if the ratio ofthe volume of the reservoir occupied by gas to the volume of the reservoiroccupied by oil (which ratio permits fixing the overall compressibility of thereservoir) is known, then only one further extensive reservoir property remainsto be determined, namely the magnitude of the reserves. A straightforwardapplication of material balance considerations will permit this determination.The problem becomes very much more difficult if we wish to determine not onlythe magnitude of the reserves but also the magnitude of water drive, if any, which is present. In principle, a combination of material balance and fluidflow considerations will permit this evaluation. Finally, if neither themagnitude of reserves, the degree of water drive, nor the ratio of oil to gaspresent in the reservoir is known and it is desired to determine all three ofthese variables, the problem could in principle be solved by a fluidflow-material balance analysis which determines the overall compressibility ofthe reservoir at various points in its history. The change in compressibilitywith pressure would provide a means of determining the ratio of gas to liquidpresent, since the compressibilities of gas and liquid vary differently withpressure variation. However, in practice this problem is probably so difficultas to defy solution in terms of basic data precision apt to be available.
T.P. 2589
Theoretical Generalizations Leading to the Evaluation of Relative Permeability
Authors: Rose Walter 
Published: April 2012

Abstract
Theoretical expressions are presented to describe wetting and non-wettingphase relative permeability relations. These expressions have then beencompared with existing published data, the conformance noted being sufficientlygood to satisfy the requirements of some engineering use. As a consequence, itmay be supposed that relative permeability characteristics of porous media nowcan be inferred from basic core analysis data, in a manner more convenient(although less direct) than presently available methods of experimentalevaluation.

Introduction
This paper presents a new approach to the problem of relative permeabilityevaluation. A classification of published discussions of relative permeabilityconcepts which have appeared in the petroleum literature will show thatpreviously emphasis has been placed on methods of experimental measurement, onthe interpretation of the data so obtained with respect to the variableproperties of the system, and on theoretical and practical considerations whichrelate relative permeability to gross fluid behavior in petroleum reservoirs.Essentially, no detailed examination has appeared which treats the fundamentalfactors controlling the quantitative features of the relative permeabilityrelation, although certain references can be cited where a qualitativeawareness of their existence and nature is indicated. This condition isexplainable in terms of the recognized complexity of the problem, and in orderto provide some basis for theoretical development, the general emphasis hasbeen placed in the past on experimental procedures of evaluation, the validityof which, in principle, could be confirmed by the analysis of well andreservoir performance. However, because of the experimental difficulties whichhave been encountered (notably, difficulties due to the so-called "endeffects"), and because of the general unreliability of field performancetests required to study the applicability of the data, relative permeabilityphenomena continue to be incompletely understood and described.
In this paper is examined the possibility of predicting relative permeabilitiesentirely from fundamental considerations. In addition, attention is called tocertain important factors, previously unemphasized in the published literature, which now can serve as a basis for the eventual experimental confirmation ofthis and similar theoretical approaches, as well as the experimental solutionof the problem in general. Therefore, the analysis presented herein has thedual purpose both of orienting future experimental activity and also ofproviding an immediate solution for the relative permeability problem, sufficiently adequate for some engineering use. It will be seen that theconclusions reached are supported by theoretical and intuitive considerations, and they are not contradicted insofar as gross features are concerned byexisting concepts and interpretations of published experimental data, except asspecifically noted.
T.P. 2563
Experiments on the Capillary Properties of Porous Solids
Authors: Calhoun John C. , Lewis Maurice , Newman R.C. 
Published: April 2012

Abstract
A report is made of experimental work performed on the capillary retentionof water within porous solid systems, the displacement being accomplished withair and various organic liquids. A portion of the experiments were designed tomeasure the lowering of vapor pressure of water within a porous solid withsubsequent conversion of such vapor pressure data to capillary pressure values.The form of the capillary pressure curve at high capillary pressures has beenelucidated from this data. Certain theoretical approaches are presented toindicate the correlation between work done by previous investigators. Thepresent work is correlated also with theory. Surface area values are calculatedfor the various core systems studied.

Introduction
Leverettt in 1941 presented a paper which gave the essential concepts ofcapillary behavior in porous solids. His presentation included both theoreticaland experimental aspects of the problem. He defined the term "capillarypressure" and applied it to an ideal porous system. His work included thedefinition of a dimensionless quantity which was a function of fluid saturationand which could be correlated with porosity and permeability for clean, unconsolidated sands. His experimental work was performed by the drainage ofwater from packed columns of unconsolidated sands. Subsequently, other authorshave presented experimental techniques which permit the determination ofcapillary pressure data on small core samples. Data have been presented onporous systems other than unconsolidated sand and with the use of liquids otherthan water. Notable among these are the works of Hassler, Brunner and Deahl, Bruce and Welge, Amyx and Yuster, and Purcell. Others have indicated theapplicability of such data to field problems without regard to the theoreticalaspects of the capillary pressure saturation function. Within the recentpublished literature there have also been reported studies of the correlations between capillary pressure data and otherfundamental properties of porous solids. It was the intent of the presentreported work to investigate the behavior noted by water and various otherliquids within porous systems in an attempt to amplify existing correlationsbetween capillary properties, surface properties, and other fundamentalcharacteristics of porous systems. The experimental work described here wasperformed as two different investigations but due to its nature it is reportedas separate phases of the same general topic.
T.P. 2640
Factors Involved in Removal of Sulphate From Drilling Muds by Barium Carbonate
Authors: Bergman W.E. , Fisher H.B. , Carpenter P.G. 
Published: April 2012

Abstract
The conditions under which barium carbonate can be used to remove sulfatesfrom drilling muds are limited. The amount of sulfate remaining in solution inthe system after treatment with barium carbonate is shown to be a function ofthe concentration of the carbonate and barium ions and the concentration ofother electrolytes. Barium hydroxide may advantageously replace bariumcarbonate when the contamination is not entirely due to anhydrite (calcium inthe system is then stoichiometrically less than sulfate) or when the carbonateconcentration is high. The effect of substances such as quebracho, phosphates, and chromates, which form complexes or precipitates with barium, isdiscussed.

Introduction
As the complexity of the operations in drilling for oil has increased, moreattention has of necessity been directed to the problems pertaining to themaintenance of good drilling mud properties. As a result, chemical treatment ofmuds has become an important factor in recent years. Some of these treatmentshave been designed to eliminate the deleterious effects of contaminants inaqueous mud systems by precipitation or other means. The most common ofsubstances encountered during drilling include sodium chloride, cement, andcalcium sulfate while various other contaminants, usually in small amounts, maybe introduced from the water, clays, and other materials used in preparation ofthe mud. In certain cases, for example where continued salt-water flow isencountered or massive anhydrite is drilled, special muds may be used so thatthe physical properties of the mud will remain satisfactory for drilling. Inother cases, it is desirable to remove the contaminants so that solubleelectrolytes in the system are maintained at low values.
For sulfate contamination, the common practice in the field is to add bariumcarbonate to precipitate the sulfate as barium sulfate. Ordinarily such aprocedure gives satisfactory results. There have been important instances, however, where addition of barium carbonate was not effective in removal ofsoluble sulfates from drilling muds, and it is to these cases that the presentpaper is directed.
T.P. 2639
Some Examples of Fluid Flow Mechanism in Limestone Reservoirs
Authors: Keller W.O. , Morse R.A. 
Published: April 2012

Abstract
The properties of limestone reservoir rocks such as the distribution anddegree of continuity of the pore systems, and the relative volumes andpermeabilities of the systems making up the complex cause large variationsbetween performance of individual limestone reservoirs and their susceptibilityto secondary recovery methods. The effects of these factors on the mechanism offluid flow cannot be adequately evaluated with presently developed concepts, laboratory data, and geological information. The observance and interpretationof the performance of individual limestone reservoirs provides, at present, themost adequate approach for evaluating the integrated effects upon performanceof the many, now immeasurable variations in the properties of limestonereservoirs.

Introduction
The development and application of techniques for increasing the efficiencyof oil recovery from natural reservoirs is a problem of primary importance tothe industry. During the past several years, a great deal of effort has beenexpended by the technical personnel of the industry toward the improvement ofpresent known methods of oil recovery, and evaluating the factors which controlthe susceptibility of particular reservoir types to economic application ofsecondary recovery methods. Providing adequate and accurate laboratory data onthe properties of the reservoir rock and its contained fluids, together withgood production statistics, are available, methods have been evolved forestimating with reasonable accuracy the performance of an oil reservoir undereither continued natural depletion or conditions imposed by introducingadditional displacing fluid into the reservoir from an extraneous sourcethrough the injection of gas and/or water.
The susceptibility of limestone reservoirs to secondary recovery by gasinjection is very much dependent upon gas-oil relative permeabilityrelationships for the reservoir in question. In a rock formation in which theporosity is of the intergranular type such as is found in sand stones and somenonfractured dolomites, a representative sample of the pore structure can beobtained in a small core plug. In this type of reservoir, it has been shownthat relative permeability data obtained from laboratory experiments can beproperly applied to evaluate the flow relationships actually observed duringthe depletion of a reservoir. In addition, a good idea of the fraction of thereservoir which will be swept by the injected gas may be obtained from thespacing pattern used and the permeability profile of cored wells. From thesedata, it has been demonstrated that reliable estimates of performance andrecoveries under gas injection operations can be made for reservoirs in whichthe porosity is of the intergranular type.
T.P. 2638
The Performance of the Ten Section Oil Field
Authors: Lietz W. Tempelaar 
Published: April 2012

Introduction
The Ten Section oil field is located in the San Joaquin Valley in KernCounty, California, about 12 miles southwest of Bakersfield in Township 30South, Ranges 25 and 26 East. The accumulation is in a low relief anticlinaldome and has a productive area of approximately 2,200 acres. Discovered in 1936as a result of seismic work, it was the first field on the floor of the Valleyto obtain production. It had a small primary gas cap, and since its inceptionhas been produced by depletion with controlled withdrawal from the gas cap tominimize blowthrough.

Structure and Stratigraphy
The Ten Section structure is an elongated anticlinal dome with flank dips ofonly about 7 degrees. A map of the field, now fully developed, and a compositelog are shown in Figs. 1 and 2. Contours shown on the map are on the top of thefirst zone, or Marker XA as indicated on the composite log.
As shown, the field has a productive closure of only some 350'Feet, and thereapparently is no faulting in the reservoir.
The productive measures in Ten Section are of Upper Miocene age and are knownas the Stevens sand. They contain thin, irregular shale or siltstone streakswhich vary considerably in stratigraphic position and thickness and apparentlyare rather discontinuous. As a result, individual sands and shales cannot becorrelated over any appreciable area, which makes it difficult to subdivide thesand body into separate zones which are distinct throughout the field. However, there are two fairly persistent siltstone bodies that at the time ofdevelopment were considered to divide the productive measures into threegeneral zones.
The first, or uppermost zone is productive over the entire field and has anaverage thickness of 180'Feet, of which some 65 per cent is sand. It had aprimary gas cap in the crestal area with an areal extent of 930 acres. Thesecond zone has a productive area somewhat smaller than the first zone, but itdid not have any original gas cap. It has an average thickness of about 360feet, of which 55 per cent is sand. The third zone has a very limited arealextent and a maximum productive thickness of 100'Feet, of which 80 per cent issand. Recently, a deeper oil accumulation, termed the "53" sand, wasdiscovered, but it is not discussed in this analysis. In the first and secondzones the water table was at 7,980'Feet subsea, while in the third zone it wasat 8,080'Feet subsea.
T.P. 2643
Multiple Condensed Phases in the Methane-Decane-Tetralin-Bitumen System
Authors: Billheimer J.S. , Yundt C.G. , Sage B.H. , Lacey W.N. 
Published: April 2012

Abstract
As a part of a general investigation of the separation of bitumen fromhydrocarbon mixtures a study was made of a restricted quaternary systemcomposed of methane, decane, tetralin, and bitumen. The work was limited to apressure of 8000 psi, a temperature of 220'F, and to a fixed relativeproportion of decane, tetralin, and bitumen. The measurements permitted thedetermination of the distribution of these components in each of the fluidphases. It was not possible to distinguish a second liquid phase in the courseof these measurements. Gas-liquid equilibrium "constants" of each ofthe components were found to vary markedly with the composition of the systemwhile temperature and pressure remained fixed.

Introduction
The separation of bitumen from naturally occurring hydrocarbon mixtures hasbeen of importance for a number of years in the production of petroleum, especially in the California area. The deposition of this material from crudeoils was noted in earlier studies of the solubility of natural gas in crudeoil. Studies of the separation of bitumen from crude oils from the Greeley andSanta Fe Springs fields were carried out. The behavior of these systemsappeared complex and studies of two restricted ternary systems involvingmixtures of n-pentane, tetralin, and bitumen, and of decane, tetralin, andbitumen, confirmed this belief. Reviews of the literature pertaining to theseparation of bitumen from naturally occurring and refined hydrocarbons areavailable.
The important effect of methane in the separation of bitumen from naturallyoccurring hydrocarbon mixtures was apparent from the earlier studies, and forthat reason it appeared desirable to investigate a restricted quarternarysystem involving mixtures of methane, decane, tetralin, and bitumen; dataconcerning the behavior of mixtures of decane, tetralin, and bitumen havingalready been obtained. This study was restricted to a pressure of 8000 psi, atemperatue of 220'F, and fixed relative proportions of bitumen, decane, andtetralin. This composite constituent, hereinafter designated as the lessvolatile constituent, was made up of 0.0455 weight fraction bitumen, 0.0909weight fraction decane, and 0.8636 weight fraction tetralin.
The experimental method involved bringing together mixtures of methane and theless volatile constituent in varying proportions in a constant volume containerat the pressure and temperature indicated above. The composition of each of thephases was determined and from this the extent of the separation of bitumen wasestablished.
T.P. 2718
Lakeview Pool, Midway-Sunset Field
Authors: Sims W.P. , Frailing W.G. 
Published: April 2012

Abstract
The Lakeview Pool of Kern County, California, was discovered in 1910 withthe drilling of Lakeview No. 1 which blew out and produced an estimated8,250,000 bbl of oil in 544 days of uncontrolled flow. The well has since beenknown as the Lakeview Gusher. Full exploitation of the pool did not take placeuntil about 25 years later. A total of 112 producing wells were completed inthe Lakeview sand through April 30, 1949. As of that date, about 30 per cent ofthe total wells drilled were still producing, with an average pool productionrate of approximately 2000 bbl per day. The cumulative oil production was about41 million bbl of oil, or 55.3 per cent of the tank oil originally inplace.
The pool is bordered on its downstructure side by a body of inactiveedgewater and water production where present has been principally the result ofconing.
Since the depletion of the greater portion of the gas energy by the LakeviewGusher, the pool has operated under gravity drive. Relatively high angle dips, good permeabilities and favorable fluid characteristics have made gravitydrainage particularly effective. Since January, 1942, the oil recovery has beenrelatively constant at about 53,000 bbl per ft drop in fluid level.Correlations between the volume of reservoir space drained and the cumulativeoil produced indicate that an ultimate recovery of 63.3 per cent of the tankoil originally in place is attainable.

Introduction
The Lakeview Pool is an outstanding example of gravity drainage. It is oneof many productive reservoirs of the Midway-Sunset Field, and is located inKern County, approximately five miles southeast of Taft and two miles north ofMaricopa, California. Its position relative to surrounding pools and to theThirty-Five anticline is shown on Fig. 1. The northern portion of the pool liesin sections 32 and 33, Township 32 South, Range 24 East, Mt. Diablo Base andMeridian, while the southern portion lies in sections 25, 26, 35 and 36, Township 12 North, Range 24 West, San Bernardino Base and Meridian. As no twosections bear the same number, they will hereafter be referred to by sectionnumber alone.
The purpose of this paper is to review the performance of the Lakeview Poolin an effort to evaluate the effectiveness of gravity drive as a recoverymechanism.
T.P. 2779
Some Preliminary Investigations of Quantitative Interpretations of Radioactivity Logs
Authors: Bush Robert E. , Mardock E.S. 
Published: April 2012

Abstract
The objective of this paper is to present practical methods of applyingradioactivity logs to problems of interest both to those engaged in evaluatingfundamental reservoir data as well as to those engaged in subsurface structuralwork. The basic theories underlying the operation of radioactivity loggingmethods are briefly discussed along with some of the problems arising in theinterpretation of the log. Relative methods of quantitative interpretation aredescribed, with a discussion of relative reference lines and specific examplesare given showing the application of these relative quantitative interpretationmethods. To show the variation of the methods described, specimen wellspenetrating formations widely divergent in point of geologic age were selectedto demonstrate the application. A relative reference line is determined for theNeutron Curve and by comparison to known petrophysical data such as porositiesfrom diamond cores, a direct quantitative relationship is developed. Theapplication of this relative calibration curve to logs of unknown wells willpermit a reasonably accurate determination of porosity in limestone anddolomite formations. Specific examples are given showing the application ofthese relative methods of interpretation to logs of the Smackover limestone inLouisiana, the Edwards limestone and dolomites of South Texas, and Permiandolomites of West Texas.

Introduction
Radioactivity logs have been used extensively by the petroleum industry fora number of years and recognition of their value has grown steadily, not onlyas tools to aid in the solution of specific stratigraphic problems, but also aspotential sources of the basic data necessary for the estimation of net pay andreserves. The value of radioactivity logs for stratigraphic work has beenpointed out in the literature, and now has long been recognized by theindustry, but the quantitative application of the logs has advanced but littlebeyond the stage of a strong conviction that radioactivity logging curves willsome day provide the information on such important quantities as the porosityand the liquid saturation of the formations.
T.P. 2780