bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Experimental Water-flood in a California Oil Field
Authors: Babson E.C. , Sherborne J.E. , Jones P.H. 
Published: June 2014

Abstract
A study of the Chapman zone in the Richfield field, Orange County, California, indicates that the quantity of oil recovered by present methods will be only asmall portion of the oil originally in place. Since the volume of residual oilis believed to be of large magnitude, an experimental water-flooding operationhas been initiated in order to determine whether water-flooding offers promiseas an economical method of recovering some of this residual oil. A singleinjection well was drilled between old producing wells, and a water-treatingplant using alum flocculation and chlorination was designed and built. Waterhas been injected into the input well for six months at rates in excess of 100bbl. per day. Production from one of the neighboring wells has increasedmaterially, the oil production having risen from. 7 to 30 bbl. and the waterfrom I to 40 bbl. per day.
While definite conclusions regarding the economic success of water-flooding inthe Chapman zone are not justified at this time, it has been demonstrated thatwater can be injected into the zone on a sustained basis and that this waterwill displace appreciable quantities of oil from the sand.

Introduction
As a result of an investigation of subsurface conditions in the Chapman zone ofthe Richfield field, it was concluded that ultimate oil recovery from this zonewould probably be low and that natural water encroachment was so localized asto be of little importance from a recovery stand-point. Furthermore, it wasfound that in many portions of the zone the wells were approaching anunprofitable level of production. When these data were presented to themanagement of the Union Oil Co., their reaction was that an attempt should bemade to develop methods of recovering at least a portion of the large quantityof oil remaining in this zone.
After some investigation, it was decided that water-flooding offered the mostlikely means of accomplishing this end, but reservoir conditions in the Chapmanzone differ so widely from those encountered in any of the flooding projectsdescribed in the literature that it was difficult to evaluate the probabilityof success. Despite encouraging results from laboratory tests, it was not evencertain that water would displace an appreciable volume of oil from the Chapmansand under reservoir conditions. Therefore, it was decided to initiate asmall-scale project, for two purposes: first, to determine whether water woulddisplace oil from the Chapman sand and, second, to obtain information andexperience for future operations? if water-flooding appeared to be a promisingmethod of secondary recovery.
T.P. 1816
Postwar Inventories of Crude Oil and Petroleum Products in the United States
Authors: McIntosh Albert J. 
Published: June 2014

Abstract
With petroleum consumption declining temporarily after V-J day, the oilindustry is urged to use this period as a kind of stopgap to rebuild itswar-depleted inventories and help cushion the effect of this decline onproducers and refiners. Higher inventories should be reestablished, sincerecent experiences have indicated that, by and large, the present inventoriesof crude oil are too low even with the tremendous current production available.The following analysis indicates that inventory levels could be built up toabout 490,000,000 bbl. by the end of 1947, an increase of about 40,000,000 bbl.over the reported stock estimated far the war's end. If at the end of the warthe military have some 20,000,000 bbl. on hand, this inventory will either beresold to the industry or certain demands that have been assumed to be met byindustry will be supplied out of these military stocks, which would leave about 20,000,000 bbl. (net) to be built up from current production. For stockrebuilding the industry could use 10,000,000 bbl. of crude plus 10,000,000 bbl.of products, totaling 20,000,000 bbl. If this were spread over a year, thiswould mean 55,000 bbl. a day. By analyzing the average inventories held in ayear with the total quantity of goods handled during the year, the followingstudy and tables indicate how far the inventories should increase in theimmediate postwar period.

Introduction
For the period immediately following V-J day, most of the petroleumeconomists have forecast a considerable decline in the total consumption ofpetroleum and its products in the United States. This will be caused by theelimination of most of the military demands and the inability of civilians toimmediately replace automobiles, burners, etc., and thus increase theirrequirements to make up for the military decline. When the automobile industryhas been back on full production for two or three years, civilians will be ableto consume much larger quantities of gasoline. Delay in the manufacture of newoil burners and the time it takes to construct new homes, adds up to the samestory for distillate fuels. In reviewing this outlook, the question has arisenwhether the petroleum industry should not use this period of lower consumptionas a kind of stopgap to rebuild its war-depleted inventories and help cushionthe effect on producers and refiners of this sudden drop in requirements. Somepersons have indicated that hundreds of thousands of barrels a day could beused for this purpose extending over a year or more. Refineries will be inexistence, which could run over 5,000,000 bbl. of crude oil a day and crude-oilproduction might be running 600,000 to 700,000 bbl. a day above the demands nowforecast for the period after V-J day.
T.P. 1870
A Series of Enthalpy-entropy Charts for Natural Gases
Authors: Granger George 
Published: June 2014

Abstract
Enthalpy-entropy diagrams are presented for natural gasses of 0.6, 0.7, 0.8,0.9, and 1.0 gravity over the pressure range of 5 to 10,000 lb. per sq. in. andtemperature range of 32 degrees to 700 degrees Fahrenheit. The charts indicatedirectly the work requirement and temperature rise for adiabatic compression ortemperature change for free expansion of natural gases.

Computation and Uses of Charts
The Mollier diagram in which the enthalpy (heat content) is plotted against theentropy with lines of constant temperature, pressure, and in some cases volume, has been found most convenient when dealing with the compression, expansion, and flow of fluids. In dealing with the flow of fluids, the sum of the increasein the enthalpy plus the increase in kinetic energy plus the increase inpotential energy of the fluid in flow, is equal to the sum of the heat and workadded to the fluid while flowing between the entrance and exit of the flowsystem.
In cases where there is no significant change in potential energy or in kineticenergy (velocity), it follows that the increase in enthalpy is equal to thetotal energy supplied to the fluid. Under such conditions the changes in theproperty of the fluid as it flows through a throttling valve, choke, or anyother similar arrangement, may be read directly from the enthalpy-entropydiagram by following a horizontal line between the known pressures.
When compression or expanding a gas by which means of a compressor or engine inwhich no heat is added to or subtracted from the gas, but only work done, thechanges in the properties of the gas may be determined along a vertical line ofconstant entropy between the entering and exit pressures. The power requiredfor the compression of the gas may be readily determined by converting theincrease in enthalpy into the desired units.
The enthalpy-entropy diagram for natural gases is to the gas engineer what thesteam diagram is to the steam-power engineer. For this reason it would beextremely convenient of a reasonably satisfactory enthalpy-entropy diagramcould be prepared as a function of the gravity of the gas. A careful study ofthe known properties of natural gas indicates that this is possible.
The effect of temperature upon the enthalpy at consistent pressure is expressedas the ?heat capacity? or ‘specific heat’ of the gas. The best available datafor natural and petroleum refinery gases indicates the relationship shown. Fromthis it is clear that the specific heat of natural gases is a function only ofthe gas gravity and the temperature at atmospheric pressure. The effect ofpressure on the enthalpy of natural gases is dependent upon the pressure-volume-temperature relationships.
T.P. 1747
An Introductory Discussion of the Reservoir Performance of Limestone Formations
Authors: Bulnes A.C. , Fitting R.U. 
Published: June 2014

Abstract
Field experience with limestone and sandstone production indicates theexistence of wide differences between the reservoir behavior of these two typesof formation. Little attention appears to have been given to the separate studyof the flow of fluids and the retention of fluids in limestones. This paperpresents data and arguments to demonstrate the existence of a difference?between the two types of formation, and urges the separate intensiveinvestigation of limestone reservoirs. All experimental data presented pertainto dolomitic limestone formations in West Texas and New Mexico.
Two kinds of porous media are recognized intergranular and intermediate.Intergranular rocks are those in which the porosity and permeability aredetermined by the geometrical properties and the sorting of the sedimentaryunits; intermediate rocks, those in which there is no direct relationshipbetween grain properties and the porosity and permeability. Limestones ingeneral are intermediate media. The partial relationship between porosity andpermeability of any class of porous media is represented by an area of finiteextent and definite shape on the permeability-porosity plane.
The horizontal and vertical variations of porosity and of permeability inlimestone and sandstone formations are discussed and compared.
Comparisons are made of connate-water content,. the relativepermeability-saturation relationship, and. capillary phenomena in the two kindsof rocks.
A number of tentative conclusions are drawn relative to the reservoirproperties of limestones; in particular,dolomitic limestones are oilbearing and apparently are oil productive in zones of permeability less than0.1 millidarcy, andprimary depletion (by gas expansion) oil saturationsmay be lower in dolomitic limestones than in sandstones.

Introduction
It is well known that the reservoir performance of limestones displays numerousirregularities when compared with that of sandstones, and that the departuresfrom "normal" behavior of limestones are more frequent and generallymore marked than in sandstones. This is particularly true of fracturedlimestones and those that have undergone considerable development of secondaryporosity.
A review of the literature of production research published during the past ISyears reveals a startling absence of theoretical and experimentalinvestigations directed specifically toward explaining and predicting theperformance of limestone reservoirs, even though such problems as theprediction of 'water encroachment and the estimation of ultimate recoveriescontinue at the. "inspired guess" stage. By far the greater part of theexperimental data reported pertain to measurements on sandstone core samples, while the theoretical studies, almost without exception, are developed from theassumption of an ideal porous medium and therefore seldom are applicable tolimestone formations.
T.P. 1791
Core Analysis Based on Vacuum Distillation
Authors: Beeson Carrol M. , Johnston Norris 
Published: June 2014

Abstract
The gravimetric-vacuum distillation method was developed to permit rapid andaccurate determinations of the oil-water ratios of small samples or sandscontaining little oil. In addition, the samples usually are so well cleaned andso little altered by the distillation at reduced pressure that rapidestimations of other physical properties may be made with the evacuatedcores.
Requiring only elementary glass-blowing technique, the distilling tubes andtraps used in determining oil-water ratios were easily fashioned from the usualglassware. A sketch and description are given of the necessary apparatus, including the cylindrical electrical heaters. The procedure, requiring about 40min., consists in raising the temperature and maintaining it between 6750 and725?F. for at least 10 min. while the pressure is held between 1 and 2 mm. Hg.The fluids condensed in the trap (cooled by a mixture of kerosine and solidcarbon dioxide) are separated in a centrifuge and the volume of water isrecorded. Determination of changes in weight with an analytical balance of allparts of the apparatus permits computation of weight of oil distilled and totalweight of oil recovered.

Introduction
In determining the oil-water ratios of core samples, distillation atatmospheric pressure has proved to be sufficiently reliable for samplescontaining moderate quantities of oil. Since small samples and sands withlittle oil are encountered, however, it appeared advisable to develop a methodthat would be applicable under these circumstances.
The gravimetric-extraction procedure" 6–9 undoubtedly is very reliable andcould be used in all tests, but the time consumed in the determination wouldoften delay field operations. This would be especially true when dealing withtight sands or viscous oils, both of which retard the extraction process.
Accordingly, the gravimetric-vacuum distillation method was developed in orderto combine the good features of both of the older methods; that is, accuracyand speed. By reducing the pressure, it was found possible to perform thedistillation at a temperature that permits the use of glass apparatus, allparts of which can be weighed on an analytical balance. Thus, the fluids may beremoved quickly from the core, the water is readily trapped and measured, andthe loss in weight of the core is easily determined. In addition, the totalweight of material condensed in the distilling tube and in the trap provides amethod of determining the oil-water ratio that is practically independent ofthe one involving the loss in weight of the sample.
The use of vacuum not only permits as much accuracy as does the gravimetricextraction process, but it actually allows an increase in speed over theatmosphericdistillation method, because of the time required to cool the metalpots from about 1200'F between runs.
T.P. 2017
Effect of Arsenates on the Viscosity of Drilling Muds
Authors: Craft B.C. , Moncrief C.M. 
Published: June 2014

Abstract
A bentonite-clay drilling mud when treated with tetrasodium pyroarsenateunderwent substantially the same reduction in viscosity and water loss as whentreated with the complex phosphates. The complex arsenate showed a slightlyhigher reversion after heating; the other arsenates showed poorviscosity-reducing properties.

Introduction
During the past 10 years the chemical control of drilling mud has become ofmajor importance in affecting the successful drilling and working over ofwells. The desired properties of drilling mud have been well established, andin obtaining these characteristics there has developed a large market forviscosity-reducing chemicals.
Viscosity reduction produced by humic acid, tannic acid, sodium silicate, sodium tannate, Calgon, and the complex phosphates has been described byLoomis, Ford, and Fidiam. The effects of treatment with complex phosphates andammonium polyphosphates on the rheological properties of muds were investigatedby Fancher and the alkali vanadates have been described by Williams.
Laboratory Investigations
It is the purpose of this paper to point out the effects of arsenates incontrolling the viscosity and gelling characteristics of a drilling mud.Viscosities and gel strengths were measured at room temperatures with a Stormerviscosimeter calibrated in centipoises and operated at 600 r.p.m. Water losswas determined at 80'F with the Baroid low-pressure wall-building tester at apressure of 100 lb. per sq. in. for 30 min. The hydrogen-ion concentration wasmeasured with a glass electrode. The bentonite-clay suspensions were preparedin the laboratory and allowed to age several days before testing.
T.P. 1944
Method for Determining Minimum Waiting-on-cement Time
Authors: Farris R. Floyd 
Published: June 2014

Abstract
A method is presented for determining minimum waiting-on-cement time, whichtakes into account the differences that exist between types and brands ofcements and such individual well conditions as depth, temperature, andpressure.
The basis for the method was determined by laboratory tests. Being a laboratorydevelopment, several steps were required to prove its merit. The first stepconsisted of laboratory tests designed to determine the minimum cement strengthrequired in wells. Basis was found for setting a minimum value of 8 lb. per sq.in. tensile strength. Next, it was shown by laboratory tests that the time to 8lb. per sq. in. tensile strength may be expressed as a function ofconsistometer stirring time to 100 "poises," the approximate relationbeing "the time to 8 lb. per sq. in. tensile strength equals the time to100 ‘poises’ times three." Next, it was shown that the time of maximumtemperature development in cement slurries, due to heat of hydration, is alsorelated to consistometer stirring time to 100 poises, but only by a factor ofapproximately two. It was shown also that the shut-in casing pressure willbuild up after cement is placed and register a maximum pressure atapproximately the same time the slurry down the hole attains maximumtemperature. From this and the relationships listed above, the general rule wasestablished that minimum waiting-on-cement time (time to 8 lb. per sq. in.)after casing cement jobs in any well is equal to the time when the shut-incasing pressure reaches a maximum, as measured from the initial mixing ofcement, times a factor of 1.5.
Cement plugs drilled in the field at the time prescribed by this formula werefound to drill "firm to hard," thus confirming the laboratorytests.
These tests prove that many of the present regulations for waiting on cementrequire a longer time than is absolutely necessary. Use of the method hereinproposed offers the possibili ty of a saving of $ 1200 per well.

Intoroduction
The length of time allowed for cement to set after casing is determined eitherby state-wide rules, field rules, or self-imposed rules written into drillingcontracts. In general, the time is dictated by experience and common practice.However, owing to differences in opinion and in experience of the variousgroups involved, waiting-on-cement time often varies from one area to the next.For example, an operator in an area where no rules exist may drill out ofsurface pipe at 24 to 36 hr., while another operator in another area may wait48 hr. or more to comply with state or field rules, although the depth of thewell, hole size, type of cement, and other data are identical. An even greaterdifference in practices will be found by making similar comparisons withrespect to oilstring cement jobs. Differences in waiting-on-cement times of 36to 48 hr. are common.
Further complicating the picture is the rather common practice of allowing morewaiting time for cement to set at the greater depths than is allowed at theshallow depths.
T.P. 1968
A New Method for Measurement of Oil Saturation in Cores
Authors: Boyer R.L. , Morgan F. , Muskat M. 
Published: June 2014

Abstract
This paper describes a new method for measuring the oil saturation of coresduring the course of fluid-flow experimentation. The method depends upon theaddition to the oil of a soluble tracer material that is the primary absorberof the X-rays incident upon the core. The paper includes a description of theX-ray equipment and intensity-measuring apparatus, calibration data for twocores, and results obtained with additional cores for various conditions of oiland water-flooding. The data and results are presented to show thepotentialities of the X-ray method at this stage of development rather than toestablish particular concepts pertaining to fluid-displacement mechanisms ofpermeable media. Further development of this method will include adequatepressure and flow-rate control in the liquid and gas-flow systems,.as well asadditional stabilization of the X-ray power supply.

Introduction
In the last several years a type of application of the' fundamentalpermeability saturation relationships has been developed which others greatpromise in the interpretation of general reservoir performance. In thesedevelopments no attempt is made to solve the detailed flow dynamics in actualoil and gas-producing systems. That problem still remains unsolved. But thepermeability-saturation phenomena are incorporated in the analysis of oilproducing reservoirs in a manner such as to reflect the true role they play incontrolling the gross reservoir behavior. In particular, they are introduced insuch a manner as to determine the gas-oil ratio of the production at any stageof depletion and, when combined explicitly with the so-called material-balanceprinciples in differential form, one can obtain a differential equationdescribing completely the average pressure and gas-oil-ratio history ofoil-producing reservoirs. While thus far they have been applied directly onlyto gas-drive reservoirs, they are susceptible of extension to partialwater-drive systems, and qualitatively the same principles are of value in thestudy of complete water-drive reservoirs. Moreover, in addition to giving ameans for computing the variation of the reservoir pressure and gas-oil ratiosvs. the cumulative production, they automatically lead to predictions of thegross ultimate recovery under natural depletion-and when properly extended theyprovide means for predicting the ultimate recovery under gas or waterinjection.
The data required for such applications are the initial fluid distribution inthe producing section, the pressure-volumetemperature data on the gas andliquid phases, and the permeability-saturation relationship for theoil-saturated zone. The former can be obtained with reasonable accuracy bymethods that are well established and available throughout the industry. Thepermeability-saturation data, however, involve techniques that are not at allstandardized.
T.P. 2124