bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Electrical Resistivity Log as an Aid in Determining Some Reservoir Characteristics
Authors: Archie G.E. 
Published: June 2014

The usefulness of the electrical resistivity log in determining reservoircharacteristics is governed largely by:the accuracy with which the trueresistivity of the formation can be determined;the scope of detailed dataconcerning the relation of resistivity measurements to formationcharacteristics;the available information concerning the conductivity ofconnate or formation waters;the extent of geologic knowledge regardingprobable changes in facies within given horizons, both vertically andlaterally, particularly in relation to the resultant effect on the electricalproperties of the reservoir.
Simple examples are given in the following pagesto illustrate the use of resistivity logs in the solution of some problemsdealing with oil and gas reservoirs. From the available information, it isapparent that much care must be exercised in applying to more complicated casesthe methods suggested. It should be remembered that the equations given are notprecise and represent only approximate relationships. It is believed, however, that under favorable conditions their application falls within useful limits ofaccuracy.

Introduction
The electrical log has been used extensively in a qualitative way tocorrelate formations penetrated by the drill in the exploitation of oil and gasreservoirs and to provide some indication of reservoir content. However, itsuse in a quantitative way has been limited because of various factors that tendto obscure the significance of the electrical readings obtained. Some of thesefactors are the borehole size, the resistivity of the mud in the borehole, theeffect of invasion of the mud filtrate into the formation, the relation of therecorded thickness of beds to electrode spacing, the heterogeneity of geologicformations, the salinity or conductivity of connate water, and, perhaps ofgreatest importance, the lack of data indicating the relationship of theresistivity of a formation in situ to its character and fluid content.
On the Gulf Coast it is found that the effects of the size of the boreholeand the mud resistivity are generally of little importance, except when dealingwith high formational resistivities or extremely low mud resistivities.Fortunately, little practical significance need be attached to the exact valuesof the higher resistivities recorded. Low mud resistivities are not common, butwhen this condition is encountered it may be corrected by replacing the mudcolumn. With the present advanced knowledge of mud control, invasion of mudfiltrate into sands can be minimized, thereby increasing the dependability ofthe electrical log. The effect of electrode spacing on the recorded thicknessof a bed is often subject to compensation or can be sufficiently accounted forto provide an acceptable approximation of the true resistivity of theformation.
T.P. 1422
Field Application of Core Analysis and Depth-pressure Methods to the Determination of Mean Effective Sand Permeability
Authors: Van Wingen N. 
Published: June 2014

Effective sand permeabilities can be ascertained from core analysis if thelaboratory data are compensated to allow for the presence of connate orresidual water. Such adjustments can be made by applying empirically derivedcorrection factors.
Effective sand permeabilities can be estimated also from analytical studiesof field depth-pressure measurements. In one method the time rate of pressurebuild-up after a well is shut in from steady-state flow is required, and in theother the direct measurement of a steady-state rate of flow and thecorresponding equilibrium pressure.
The results of the investigation discussed in this paper demonstrate thatthese methods for determining mean effective sand permeabilities can becorrelated.

Introduction
In recent years many investigators have demonstrated the practical value ofan accurate knowledge of the physical and dynamical characteristics ofreservoir sands containing oil and gas. Of these factors, which serve tocompletely define a porous medium as a container or carrier of fluids, thedynamical characteristics are of particular interest to the production engineerbecause they afford a direct measure of the rate at which the oil or gascontent of a reservoir will become available. The constant that definesdynamically the porous medium as the carrier of a homogeneous fluid in viscousmotion is the "permeability."
Core-Analysis Method
The generally accepted practice in compiling permeability data has been toanalyze in the laboratory core samples taken in the course of drilling throughthe productive horizon, and to obtain the mean measure of the productiveability or permeability for the interval open to production by graphicalintegration of the permeability profile.
An average permeability ascertained in this manner, however, is useful tothe production engineer only for comparisons of wells drilled in the samehorizon, as permeabilities determined in the laboratory are measures of onlythe ability of a porous medium to transmit a single fluid. As a result of manyinvestigations, it has been shown, however, that under actual reservoirconditions water is coexistent with the petroleum and that its presence greatlyreduces the permeability of the sand to oil.
T.P. 1464
Geology and Development of the Paloma Field, Kern County, California
Authors: Wood James T. 
Published: June 2014

Stratigraphy, structure and closure of the Paloma field are discussed, withsome details regarding the present state of development. The Paloma anticline, a large dome modified by faults, is the largest single closed dome in thesouthern San Joaquin Valley without surface outcrop or topographic expression.It owes its discovery to geophysics. Of nine wells drilled to the Stevens sand, seven are productive. The ultimate productive area may approximate 3000 acreswhen the limits of the field are determined.

Introduction
The Paloma field derives its name from the Paloma school, 1/2 mile north ofwhat is now the center of the field.
The field is 17 miles southwest of Bakersfield, in the south central part ofthe San Joaquin Valley (Fig. I). The present developed area and its expectedextensions are in townships 31 and 32S., R.26E. It is the most southerly ofseveral fields that produce from the Stevens sand zone.
The first well to produce condensate was a joint test drilled by the WesternGulf Oil Co. and The Texas Co. near the center of sec. 3, T.32S., R.26E., wellNo. 54–3. This well was completed on Aug. 31, 1939, at a depth of 10,178 ft.The initial production was 2280 bbl. a day of condensate and 14,750,000 cu. ft.of gas (1/2-hr. gauge) through a 3/8-in. bean.
Prior to the drilling of this well, the Ohio Oil Co. discovered anddeveloped a small gas field, which embraces a part of three townships abouttheir common corner but lies chiefly in secs. 31 and 32, T.3IS., R.26E. Thefirst well was completed on July 1, 1934, at a plugged depth of 5239 ft. afterhaving been drilled to 7957 ft. Production was found in a 59-ft. zone 110 ft.below the
Fourth Mya bed, within the San Joaquin clays. Until recently this field wasknown as the Buena Vista gas field. It is now carried by the Division of Oiland Gas as the Paloma gas field. Production within the Paloma gas field isderived from six wells, producing from several different zones in the intervalfrom 4177 to 5548 feet.
T.P. 1471
Calibration and Control of the Supercentrifuge for the Fractionation of Oil-well Drilling Muds
Authors: Oliphant S.C. , Houssiere C.R. , Fancher George H. 
Published: June 2014

Abstract
Drilling mud can be an item of great expense on the Gulf Coast. In order tounderstand the nature of a drilling mud, it is desirable to know thecomposition and size of the mineral particles that are present. Thesupercentrifuge has been adapted to the fractionation of mud, and this paperdiscusses the calibration and methods of operation and control. An alignmentchart has been prepared, which was found useful in this work. Typical data areincluded, showing the comparative reliability of the method.

Introduction
The application of the Sharples supercentrifuge to the determination of bothparticle size and the particle-size distribution in colloidal systems has beenpresented previously. While other methods such as elutriation, the Casagrandesedimentation method, microscopy, and the ultracentrifuge are available fordetermination of the sizes of particles, the supercentrifuge has the advantagesof large capacity, rapidity of determination, simplicity of operation, and lowmaintenance and operating costs.
The Sharples supercentrifuge consists essentially of a balanced cylindersuspended from a vertical drive shaft that is driven by either air, steam, oran electric motor. The supercentrifuge and the equipment used for its operationare shown in Fig. I as set up in the laboratory.
The mud suspension to be centrifuged, usually 2 per cent or less of solidsby weight, is allowed to flow into the bottom of the hollow rotating cylinderthrough a small nozzle. From the nozzle, the suspension flows upward parallelto the wall of the bowl and out through channels that open into the bowl nearthe axis of rotation.
T.P. 1530
Factors Influencing Electrical Resistivity of Drilling Fluids
Authors: Sherborne John E. , Newton William M. 
Published: June 2014

The relation between the properties of electric logs and the fluid used indrilling a well is briefly discussed in this paper, and the fact that theresistivity of the drilling mud and its filtrate can appreciably affect suchlogs is shown.
Apparatus was designed and a procedure established to determine the effectof various factors on the resistivity of drilling mud. Five muds commonlyemployed in California were tested and the following observations weremade:The effect of raising the temperature from 80?F. to 180?F. is to decreasethe resistivity of the mud or filtrate approximately 50 per cent.The resistivity of the mud in most cases closely approximates that of itsfiltrate.The change in the resistivities of muds caused by the addition of chemicalis not the same function of the amount of chemical added for each mud.The effect produced by increased sodium chloride content is to reducemarkedly the resistivity of the mud and its filtrate.Weighting materials, such as Baroid and limestone, tend to increase theresistivity of drilling mud.Cement and counteracting reagents reduce mud resistivity.

Introduction
During recent years, the practice of "electrically logging" ageologic formation by means of a system of electrodes lowered in a well borehas provided data of inestimable value concerning the nature of the sedimentspenetrated. Thus, it is generally possible, by means of electric logs, todistinguish readily the differences between shales, sandstones, cherts, limestones, and other rock forms, The distinguishing characteristics recordedin this manner have made possible long-range and closely detailed mapping andvisualization of deeply buried structures to a degree not to be obtained with areasonable expenditure of money by any other means at present in use.
Besides being of value in correlation work, electric logs have been found, in some instances, to be useful in estimating the nature of fluid containedwithin the pores of a rock. In special cases, even the relative permeabilitiesat different horizons have been determined. That electric logs should reflectin some measure such physical properties of rocks as porosity and permeabilityand, in addition, give rise to data pertaining to the fluid content of rockinterstices, becomes evident when the conditions giving rise to the electricalphenomena measured are known. However, it is not the purpose of this paper toreview the present status of electric logging; rather, the reader is referredto the papers cited on page 220 for the principles and practice involved.
T.P. 1466
An Engineering Study of the Magnolia Field in Arkansas
Authors: Winham H.F. 
Published: June 2014

Abstract
The history, development, subsurface geology, production, economics andestimated reserves are discussed in this paper. The Magnolia structure is ananticline with a known maximum structural relief at 372 ft., and the arealextent of the producing acreage is 4494 acres. Production is obtained from theSmackover oolitic lime and 116 successful wells have been drilled. The field, which was developed on 40-acre spacing, has been under strict control. It isbelieved to be producing with a strong water drive. To date it has producedmore than eighteen million barrels and the estimate of ultimate recovery is 220million barrels.

Early History
The Magnolia field is in Columbia County, Arkansas, T. 17 S., R. 19 and 20W. Various geologists had long been interested in this general area, and asearly as 1921, John F. Magale was able to define a surface structure.
The first wildcat, one of the first in Columbia County, was drilled in 1923by Mid-States Oil Co., in sec. 10, T. 17 S., R. 20 W. This well was about 11/2miles northwest of the Kerlyn Oil Company's discovery well and was based onsurface geological work done by Jewel and Dobie. Subsequently, several shallowwells that were not carried below the Upper Cretaceous beds were drilled in theimmediate area of the discovery well, but none of them contained any commercialshowings of oil or gas. In the latter part of 1935, Elam and Magale (orSouthwood) Garrett No. I was located in sec. 13, T. 17 S., R. 20 W., 3/4 mileeast of the discovery well. It was drilled to a total depth of 4018 ft. in thelowermost Glen Rose beds but failed to obtain any showings of oil or gas.
Interest had been stimulated in this general area, however, by the discoveryof several oil fields, mainly Glen Rose oil production in the Rodessa field inLouisiana in 1935, Smackover lime production in Snow Hill in May 1936, production from the Cotton Valley formation in Schuler in 1937, and Smackoverlime production from the Buckner field in November 1937. With this backgroundand subsequent seismic work, which was carried on partly because the oldshallow wells drilled in the township had shown evidence of closure in theUpper Cretaceous beds, the discovery well, Kerlyn Oil Company's Barnett No. I, sec. 14, T. 17 S., R. 20 W., was originally projected to a total depth of 6300ft., to test the equivalents of the Morgan sands of the Cotton Valley series, then producing at Schuler. The well was carried to a depth of 6325 ft. andtested the objective beds without finding commercial production.
T.P. 1491
Determination of Oil-well Capacities from Liquid-level Data
Authors: Rodd Charles C. 
Published: June 2014

Abstract
Prior to 1938, proration procedure in Kansas required the physical testingof wells in order to set up a basis for allocating production. Subsequently theuse of liquid-level data and bottom-hole pressure data was authorized oncertain types of wells as a basis for calculating well capacities, therebypermitting wells to be tested at low rates and with small volumes ofproduction.
This paper gives some attention to the equipment used for obtainingliquid-level data but in general it is devoted to the theoretical and physicalfactors involved in well testing by drawdown methods. These tests are dividedinto two classifications:liquid-level data used directly to calculatecapacitiesliquid-level data and liquid-level measuring equipment usedin connection with other data to determine bottom-hole pressure. Equations andcalculations for both types are shown.
Well capacities calculated from fill-up data have not been used generallybut offer a simple means of testing some wells. Theoretical factors andcalculations for such tests are shown.
In the state of Kansas, proration laws required that the "ability of awell to produce" be given consideration in state allocation orders and formany years this was the only factor used in prorating the allowed oil. The"ability of a well to produce" was the quantity of oil that could beobtained from a well in a prescribed period, usually 24 hr. Early in thehistory of State-regulated proration, Kansas operators realized that, unlesssome restriction were placed upon equipment, the competition between producersto obtain large well "potentials" might result in a race to install thelargest pumping equipment. Consequently, restrictions were placed upon the sizeof tubing and length of pump stroke that could be used in pumping wells duringpotential tests. Later, restrictions were placed also upon the size of tubingand chokes that could be used in flowing walls.
T.P. 1475
Reservoir Analysis and Geologic Structure
Authors: Bugbee J.M. 
Published: June 2014

Abstract
The engineer and the conservationist agree that effective water drive is thedesirable reservoir production mechanism. Water drive may result either fromthe expansion of edge water, the reservoir water bordering an oil pool, or fromthe artesian flow of edge water from the outcrop. Thus, the extent of thereservoir has an important bearing upon both the rate and the ultimate quantityof water influx to an oil pool.
Lens-type reservoirs are generally recognizable, but the complete structureof the more important domal types, having possible limitations from crestal andsynclinal faulting, is not well understood. The delineation from cores, electrical logs and exploitation phenomena of the crestal portions ofreservoirs is increasingly exact. This paper suggests that inference from thesefactual pictures, combined with the scattered well and geophysical data of thesynclines and with consideration of the dynamics of structural formation, maybe applied to solving the complete geologic structure. Since faulting on thedomes and in the synclines may effectively seal and thus limit the size of areservoir and bar additional water influx, consideration of geologic structureand its possible effects is essential to complete analysis and prediction ofreservoir performance.

Introduction
Implicit in reservoir studies is the fact that the oil must be displacedfrom the reservoir rock by some other fluid, either gas or water, and thisunderstanding yields the terms descriptive of the major reservoir productionmechanisms, gas expansion and water drive. Three recent papers make clear theeconomic and conservation preeminence of water drive as a production mechanism;in fact, the title of the latest of these is "Production under EffectiveWater Drive as a Standard for Conservation Practice."
There appears to be an assumption at times among analysts that theeffectiveness of a water drive is solely dependent on the rate of oilproduction; that is, if water drive appears to be insufficient or lacking, alower oil-recovery rate would increase or reveal it. This assumption mightresult from the fact that the analysis has been wholly developed during theperiod of production curtailment; that is, since 1929. The writer takes it thatthe recurrent phrase in De Golyer's paper, "some degree of waterdrive," is related to this assumption. In California, an extraordinaryphrase, "inactive water drive," is rather common and the connotation ofuncertainty regarding our knowledge of reservoir performance is evident.
T.P. 1527
Relationship between Velocity, Oil Saturation, and Flooding Efficiency
Authors: Earlougher R.C. 
Published: June 2014

Abstract
Based on laboratory tests conducted with the use of fresh core samples aswell as a considerable amount of field data obtained from numerous water floodsin northeastern Oklahoma, it appears that for any given oil saturation there isa critical maximum velocity above which the oil-recovery efficiency falls offvery rapidly. In effect, when a water flood is operated above this criticalvelocity, the injected water-oil ratio rises extremely fast, thus shorteningthe economic life of the flood and reducing the ultimate oil recovery. Thiscritical velocity apparently varies considerably with the percentage of oilsaturation of the sand, so that in effect the higher the oil saturation at thebeginning of a flood the higher the velocity that can be used successfully. Inreviewing several of the earlier floods in the Mid-Continent area, it isconcluded that most of the failures were due to two things:too Iowan oilsaturation, such as 30 per cent, andtoo high water-injection rates.
Although considerably more field data are necessary to establish definitelimits, it would seem that the proper field injection rate for a 330 by 330 or440 by 440-ft. spacing varies from approximately 1 bbl. per foot of sand perday where the oil saturation is as low as 30 per cent up to 5 bbl per foot ofsand per day when the oil saturation is as high as 45 to 50 per cent.

Introduction
With secondary recovery by water-flooding receiving more and more attentionthroughout the industry, a greater working knowledge of multiphase flow underfield conditions becomes more and more necessary. A great deal of research hasbeen carried on in highly idealized laboratory conditions, from which certaintrends have been indicated, but with few exceptions no direct application tofield use has been reported. Widely varying conclusions have been drawn fromthe mass of idealized laboratory experiments and often this divergenceapparently was due to the neglect of connate or interstitial water.
Since interstitial water is such an important factor in water-floodingoperations, it then follows that any laboratory flooding experiment mustnecessarily take it into account; and since it is difficult to set uplaboratory models to allow for interstitial water, the next best procedure isto use fresh core samples for such tests. Even this procedure has itsdifficulties, inasmuch as it is possible to run only one flooding test on eachsample, as each sample differs somewhat in character from all other samples.However, this disadvantage can be overcome to a large degree by the use of anextremely large number of samples.
T.P. 1592
Permeability as a Function of the Size Parameters of Unconsolidated Sand
Authors: Krumbein W.C. , Monk G.D. 
Published: June 2014

Abstract
The relation between permeability and the size parameters of unconsolidatedsand is approached by considering sands as logarithmic frequency distributionshaving the basic parameters mean size and standard deviation. Sieve separateswere mixed in accordance with the normal logarithmic probability law, so thatthe mean and standard deviation could be varied at will. Experiments wereconducted in which one parameter was kept fixed and the other varied; in thismanner the dependence of permeability on the individual parameters wasevaluated. It was found that permeability can be expressed as the product of apower function of the mean size and an exponential function of the standarddeviation.

Introduction
Earlier studies of the effect of size of particles on the permeability ofunconsolidated sand have shown that the permeability varies with the square ofsome average diameter. This was first pointed out by Hazen in 1892 and verifiedby Slichter in 1898. Hazen's mean size was defined as the 10 percentile of thecumulative curve (i.e., size that is smaller than 90 per cent of thedistribution and larger than 10 per cent). Slichter's effective size, on theother hand, was found by Wilsey to agree with the 31 percentile. Fair and Hatchfound that the geometric mean size of sieve separates yielded the same powerfunction; Hulbert and Feben found that the permeability of sieve separatesvaried as the 1.89 power of the median diameter (i.e., the size associated withthe 50 percentile of the cumulative curve).
Relatively few studies included the effect of the "sorting" of thesediment on the permeability. It was recognized that the nature of the sizedistribution, in terms of the spread of the particles about the mean, affectsthe permeability, but no systematic investigations of this effect are known tothe writers. Cloud demonstrated that the effect of the grain-size distributionon permeability is definitely measurable. In the present paper the authorsinvestigate this relation analytically, and show that the effects of the sizeparameters on permeability may be predicted for at least a restricted set ofconditions.
T.P. 1492