bluuebunny/crossref_metadata_2025_split huggingface dataset:
Slim-hole Drilling on the Gulf Coast
Authors: Alcorn I.W. 
Published: June 2014

The cost of drilling in the past few years of proration and ever decreasingallowables has received increasing thought and study. It seems to parallel thestrides made with respect to pumping problems in 1932 and 1933. Low profitmargins stimulate the search for economies.
Any discussion of slim-hole drilling involves a multitude of abstract values, and the problem can be attacked only by a study of records and rationalthinking. In a measure, traditional methods must be studied with a questioningattitude.
The words "slim hole" may be somewhat misleading, as the term isentirely relative. For that reason I wish to define it as used in thisdiscussion. On the Gulf Coast, I would define a normal hole as one in which 103/4-in. surface casing has been set and below which a 9 7/8-in. hole is dug.With this as a datum, holes of larger diameter below surface would be called"large holes," with 12 1/4 in. as the "extra large" class andholes of smaller diameter classed in the slim-hole range, 6 1/4-in.representing about the minimum size. The optimum size has not been definitelydetermined, but the preference is for a program that would call for setting 85/8-in. surface casing and digging a 7 3/4-in. hole. Different sections of thecountry might very properly deviate from this practice because of differencesin depth, formations, regulations, or other factors.
This paper will be confined to a discussion of the drilling of exploratorywells, as the drilling of this class of wells is quite a different problem fromthat of drilling a proven field, although many of the same considerations applyin both cases, as will be apparent.
Although for many years shallow slim-hole and core-test holes of small diameterhad been dug, it was not, I believe, until the fall of 1937 that seriousconsideration was given to its application in drilling wells 7000 ft., 8000 ft.and 9000 ft. deep on the Gulf Coast. This does not mean that nearly all suchwells drilled on the Gulf Coast now are of the slim-hole variety, but only thatefforts have been aimed in that direction with very encouraging results andthere has been a very definite trend to reduce the size of holes, a trend thatprobably will continue.
As to exploration policy, there appear to be two distinct and opposite views.The one usually followed in the past was more or less designed to "shootthe works" on one well. Generally on the Gulf Coast, the depth at whichproduction might be obtained is limited by the drilling equipment andeconomics. With this thought in mind, wildcat wells are often planned with theidea of carrying the depth to 10,000 ft., or even 15,000 ft. All of thepossible hazards are anticipated and the general drilling and casing programsare so predicated. Such wells contemplate the drilling of large-diameter holes;the setting of at least one protective string of casing and an extensive coringpolicy, all of which finally adds up to an expensive well.
T.P. 1305
Scope and Content of the Petroleum Engineering Curriculum
Authors: Uren Lester C. 
Published: June 2014

This paper reviews the industrial trends and changes in educational conceptsthat have led to the development of the modern petroleum engineeringcurriculum. A trend toward emphasis on engineering fundamentals is noted. Whilemost universities are committed to the traditional four-year engineeringprogram, it is agreed that more than four years is necessary for academicpreparation of the petroleum engineer in all phases of his profession. Theauthor proposes a coordinated program of undergraduate and graduate trainingthat will permit of adherence to the general pattern of the present four-yearengineering course, with provision for extension of the program intospecialized graduate courses of professional character. In the latter, emphasismay vary with the interests and objectives of the individual student. Aspecific undergraduate curriculum is proposed in which upward of 80 per cent ofthe available time is devoted to engineering fundamentals. A broad survey ofthe professional field is afforded in courses grouped in the third and fourthundergraduate years, but detailed treatment of the professional aspects ofpetroleum engineering is reserved for the graduate program.

Introduction
Of necessity, engineering curricula must ever be changing to reflect the newtechniques, the changing concepts that are presented as the engineeringindustries develop and unfold. Particularly is this true of the youngerengineering curricula representing comparatively new and rapidly changingindustries such as the petroleum industry. Institutions that planned theirpetroleum engineering curricula a decade or two ago now find that the petroleumindustry has become vastly more technical in its requirements. Entirely newmethods and techniques have come into vogue and must be given place in thecurriculum, and some of these are of a character that demands changing emphasisin the fundamental preparatory subjects. College and university facultiescannot complacently assume that curricula in this field that were consideredappropriate 10 or 20 years ago still reflect the needs of the industry thatthey are designed to serve. If they do, their graduates will be poorly equippedto meet the requirements imposed upon them by a rapidly changing industry.Perhaps it is not too much to expect academic authorities to anticipate thetrends of industry and equip their graduates with what they will need to attainleadership 10 or 20 years after graduation. Whether or not this desirableobjective is possible, there is no excuse for allowing curricula to fall behindthe current needs of industry.
T.P. 1350
A Comparison of Marsh-funnel and Stormer Viscosities of Drilling Muds
Authors: Owen J.E. 
Published: June 2014

Experiments on twenty-six drilling muds were carried out in an effort toestablish a correlation between the apparent viscosity values for these muds asobtained with the Marsh funnel and the Stormer viscometer. This required acalibration of both instruments in which the density of the calibrating liquidswas taken into account. Corresponding to the Marsh-funnel viscosity values thatwere obtained at 1500 c.c. in, 1 qt. out, equivalent Stormer viscosity valueswere obtained at a Stormer cylinder test speed of approximately 1100 r.p.m.Further, a linear relation between the logarithms of the Stormer cylinder testspeed and the resulting apparent viscosity was found to exist for the mudstested for 200 to 1000 r.p.m. The significance of the slope of this linearrelationship is discussed as it applies to the field use of drilling muds. Itwas concluded that Marsh-funnel viscosity measurements are expressible inabsolute units that may be correlated with Stormer viscosity measurements, provided these are made in the manner described in the paper.

Introduction
The Marsh funnel is used almost universally to determine the viscosity ofdrilling muds in the field. The Stormer viscometer is commonly used todetermine the viscosity of drilling muds in the laboratory. With the Marshfunnel, the time required for one quart of mud to flow out of the funneloriginally filled with 1500 c.c. is often taken as the measurement ofviscosity. With the Stormer instrument, drilling mud is tested at a cylinderspeed of 600 r.p.m. and by means of calibration data the apparent viscosity isexpressed in absolute units. Neither of these instruments is an absoluteviscometer, and apparent viscosities obtained with either are influenced by thearbitrarily standardized conditions under which the measurements are made.
It is disconcerting to the man in the field to be told that laboratorymeasurements of the viscosities of a group of muds differ widely, when he hasalready observed that they have identical viscosities when tested in the Marshfunnel. Drilling muds are not perfect fluids, therefore it is not surprising tofind a lack of correlation between the apparent viscosity of a mud asdetermined with the Marsh funnel and that determined with the Stormerviscometer.
The work described here was undertaken to develop a correlation betweenMarsh-funnel and Stormer viscosity measurements. To a considerable degree thishas been accomplished. This study has resulted not only in a betterunderstanding of the two viscosity instruments and the data obtainable fromthem, but has given considerable information regarding the viscositycharacteristics of drilling muds.
T.P. 1373
Steady Flow of Gas-oil-water Mixtures through Unconsolidated Sands
Authors: Leverett M.C. , Lewis W.B. 
Published: June 2014

The dynamic behavior of a multiple fluid system is completely describable interms of driving forces and resistances to flow. The latter are proportional tothe viscosity of the fluid under consideration and inversely proportional to aproperty of the system termed the" effective permeability" to thatfluid, a property therefore defined by this relation.
Since three phases are usually present in oil reservoirs, it is essential toknow the effective permeabilities to the several fluid phases, and therelationship between the composition of the fluid in the pore space and that ofthe flowing stream, in order to handle satisfactorily certain problems of oilproduction. In this regard, there are many unknown factors and parameters, andmany that can be evaluated only indirectly. However, it is expected that workalong lines similar to this present undertaking will help materially in solvingthese problems.
Previous workers in this field have investigated the two-phase systems, water-gas, water-oil in unconsolidated sands, and water-gas in consolidatedsands. The extension of the study of the flow of heterogeneous fluid systemsfrom two to three phases involved only slight changes in technique. Theapparatus used in the present work, except for slight changes to be described, was that used by Leverett in his water-oil experiments. Correlation andinterpretation of data were made by methods analogous to those used in two-phase work. The relative permeability to a phase-the effective permeabilitydivided by the permeability of the system to a homogeneous fluid-was employedthroughout in correlating the rate of flow of that phase with the compositionof the pore space.
Quantitative measurements of two independent physical properties of the systemwere required to determine the composition of the pore space. As in thetwo-phase work, the fraction of water was determined electrically. The gasfraction was determined by measuring changes in volume accompanying measuredpressure changes. Suitable account was taken of the solubility of the gas inthe liquid phases, and of the vapor pressure of the water phase. Since thiswork was exploratory in nature, no attempt was made to obtain highly accuratenumerical results. Reasonable precision and reproducibility were sought.

Experimental Procedure
Variables Considered.-Of the properties of the fluids, the oil viscosity ismost likely in practice to vary widely. Variations in oil viscosity weretherefore included in this work, but variations in other properties of thefluids are as yet unexplored. It appears unlikely that the normally encounteredvariations will produce significant changes. The observations were made atfairly high pressure gradients, no attempt being made to detect a variation ofthe relative permeabilities with pressure gradient.
T.P. 1206
Some Factors Controlling the Pumping Time of Oil-well Cements
Authors: Neighbors Glen R. , Cromer Sylvan 
Published: June 2014

High subsurface temperatures and pressures are making cementing operationsmore difficult as deeper producing horizons are being sought. Recordedbottom-hole temperatures above 200?F and pressures in excess of 12,000 lb. persq. in., obtained by combining hydrostatic and pump pressures, are notuncommon. Insufficient time is available for proper placement of standardPortland cement, because of the shortened setting time produced by theseexcessive temperatures and pressures, therefore special types of cements havebeen developed to overcome these difficulties. From the standpoint ofplacement, the ideal slurry would be one that would remain fluid long enough tobe placed, then harden rapidly, so that there would be a limited amount ofcontamination and the well could be placed on production in a minimum of time.It is highly desirable, therefore, that some method be devised to measureaccurately the time that any slurry will remain in a fluid state while beingpumped into the well.
To study the effect of elevated temperature and pressure on fluidity, theauthors have developed the pressure-type consistometer (Figs. 1 and 2)described below, and are presenting data obtained with it, using slurries ofboth quick-setting and slow-setting cements. Studies were made over atemperature range from 110? to 270?F., and a pressure range from atmospheric to3000 lb. per sq. inch.

Apparatus
The fluidity of cement slurries at atmospheric pressure is usuallydetermined with the Halliburton consistometer or the Thickening Time Tester.These instruments are similar, in many respects, to an ordinary ice-creamfreezer. The slurry to be tested is placed in a container that is rotated at aconstant speed with an electric motor. Constant temperature is maintained bysurrounding the container with a thermostatically controlled bath. The torqueon the paddles, which is proportional to the force needed to shear the slurry, is indicated on a scale. The Halliburton instrument is calibrated from 0 to 100poises against fluids of known viscosity.
T.P. 1399
Effectiveness of Gravel Screens
Authors: Sage B.H. , Lacey W.N. 
Published: June 2014

The results of an extensive experimental program relating to theeffectiveness of gravel screens have been correlated. The factors considered insome detail include gravel size and condition of packing, sand size and sizedistribution, fluid velocity, fluid viscosity, and thickness and arrangement ofgravel screens. Good agreement between calculated values based upon probabilityconsiderations and experimental results relating to the influence of thethickness of the gravel screen was obtained. All of these factors are treatedin the correlation in order that their influence may be taken into account inascertaining the characteristics of an effective gravel screen for a particularset of conditions. The details of the experimental program are not given in thepresent paper but a description of generalized behavior and typicalexperimental results are recorded in graphic form.

Introduction
Gravel screens have been placed in water and oil wells for a number of yearswith the dual objective of increasing the productivity and decreasing theentrance of sand into the well bore. An understanding of the factorscontrolling the effectiveness of gravel screens in this connection is ofindustrial interest because it will lead to the proper selection of gravel.Some of the fundamental considerations involved in the migration of sandthrough a coarser body of porous materials were investigated by Coberly andWagner, and further experimental work has been carried out by Gumpertz.Apparently the pertinent phenomena are somewhat complex and are influenced bymany variables. The present paper deals with the prediction of the behavior ofgravel screens under the conditions encountered in practice but does notattempt to discuss the experimental methods or results that were obtained as abackground and upon which the prediction is based.

Influence of Gravel Screens Upon Productivity
The use of a gravel screen may increase the productivity of a well byincreasing its effective diameter, and this constitutes one of the objectivesof its use. The permeability of most gravels and coarse sands that are employedin practice is so large compared to that of the sand in place that relativelylittle loss in production rate will arise from the use of material fine enoughto cause the desired resistance to sand migration.
T.P. 1325
Calculation of Theoretical Productivity Factor
Authors: Evinger H.H. , Muskat M. 
Published: June 2014

A method has been developed whereby one may calculate the productivityfactors of producing formations from a knowledge of the reservoir conditions.Account is taken not only of the heterogeneous character of the gas-oil flowsystem but also of the detailed variations with pressure of the shrinkage andviscosity of the oil, the solubility of the gas in the oil, and even thevariability of the gas viscosity and the deviation of the gas from idealbehavior. Curves are shown giving the results of numerical calculations on theproduction rate as a function of the pressure differential for a highpressureand a low-pressure system, three values of gas-oil ratio being treated in eachcase. Curves are also given showing the variation with distance from the wellof the pressure, oil saturation, and permeability. The effect of connate wateris briefly discussed in relation to the apparently large discrepancies betweenthe calculated and observed productivity-factor values.

Introduction
The significance of the productivity factor as a measure of the capacity ofan oil-bearing formation to produce is well recognized; for it is the compositeand integrated resultant of the physical properties of both the porous mediumand the fluid stream passing through it with respect to the ease with which theparticular petroleum fluids present in the formation can flow through it andinto producing wells.
The most direct method of determining the productivity factor of a wellconsists, as is well known, in the simultaneous measurement ofreservoir-pressure differentials and rates of production and the expression ofthe data in terms of rate of flow per unit pressure drop. Actual measurementscarried out in this manner on producing wells have given factors that generallylie in the range of 0 to 100 bb1. per day per pound pressure drop. This widerange arises not only from variations in permeability but also from the varyingsand thickness of producing formations.
T.P. 1352
Density of Crude Oils Saturated with Natural Gas
Authors: Standing Marshall B. , Katz Donald L. 
Published: June 2014

Density data are reported on 15 saturated hydrocarbon liquids in the rangeof 35? to 250?F. and 1000 to 8220 lb. per sq. in. The apparent liquid densitiesof methane and ethane are shown to vary with the density of the system in whichthey are present. A method is proposed whereby the densities of liquidhydrocarbon mixtures containing both methane and ethane in solution may becomputed at elevated temperature and pressures within the accuracy of usualengineering computations. A method of computing the shrinkage of crude oilsbased upon the gas-oil ratio, gas analysis, and crude gravity is outlined.

Introduction
The densities of naturally occurring liquid hydrocarbon mixtures areimportant in many petroleum engineering computations. Calculation of theshrinkage of a subsurface sample of crude oil as the natural gas is evolved isone example of the use of liquid-density data.
Sage, Hicks, and Lacey have presented a method of computing the density ofhydrocarbon liquid mixtures based on partial molal volumes. Katz has indicateda method based on the principle of additive volumes of the components and usingapparent densities for methane and ethane.
T.P. 1397
Calculation of Productivity Factors for Oil-gas-water Systems in the Steady State
Authors: Evinger H.H. , Muskat M. 
Published: June 2014

A method of calculating productivity factors for oil, gas, and water systemsin the steady state is presented as an illustration of the quantitativeapplication of the fundamental data on the flow properties of heterogeneousfluid systems. While the numerical results of the calculations cannot beapplied directly to field conditions, because they are based on permeabilitydata for unconsolidated sands and involve specific assumptions regarding thenature of the reservoir fluids, the methods of analysis and interpretationshould have significance in considering certain specific field situations whenthe necessary field and laboratory data become available. Moreover, it is feltthat even under the idealized conditions to which the numerical calculationsrefer they should serve to give at least the orders of magnitude of the effectsof gas-oil ratio and connate water on observed productivity factors. Within theindicated limitations, the computations imply that the foregoing factors canexplain only a part of the apparent discrepancy between the homogeneous fluidproductivity factors and those obtained recently in field measurements on theWest Coast.

Introduction
Sufficient laboratory research has been carried out in the last severalyears on the fundamental features of the flow of heterogeneous fluids throughporous media to call for consideration of what can be done with this type ofinformation. It has, of course, already led to a much clearer generalunderstanding of the mechanics of oil production. However, examples of thequantitative application of the results of such laboratory studies are few inthe literature. Part of the explanation for this fact lies undoubtedly in thelack of sufficient laboratory data relating to practical fluids and sandsystems such as would occur in actual oil reservoirs. However, unless it can beshown that if such data were obtained quantitative applications could be made, serious doubt may be cast upon the desirability of carrying on furtherextensive experimental research work on fluid flow.
The purpose of this paper is to present one approach to the problem ofquantitative application of laboratory data to practical field problems.Because the published results on the basic experiments with three-phase fluidsystems in porous media are limited entirely to unconsolidated sands, thenumerical applications made here will not pertain directly to any actual fieldsituation. However, they should serve to illustrate what could be done withfundamental laboratory data if they were extended to cover the field ofconsolidated sands. From this point of view, it is hoped it will serve toencourage further laboratory research on this problem.
T.P. 1416