bluuebunny/crossref_metadata_2025_split huggingface dataset:
Future Demands on Oil Industry of United States
Authors: Pogue Joseph E. 
Published: June 2014

In 1920, 531 million barrels of crude petroleum were consumed in the UnitedStates. As imposing as this figure is, the fact that the domestic consumptionof crude petroleum has increased at an average rate of 10 per cent. a year forthe past decade is more striking. Will this rate of increase in demandcontinue? If so, the year 1930 will call for 1260 million barrels of petroleum- a staggering volume. On the other hand, may we expect the demand forpetroleum to grow as rapidly as it did when the automotive industry was havingits most phenomenal expansion? If not, to what extent will the growth of oilrequirements decrease? When and to what degree will the petroleum industrybecome affected by the economic law of diminishing returns? Obviously, thismatter requires careful analysis, especially as both national and industrialplanning must be predicated upon present estimates of the requirements of thefuture. The purpose of this paper, accordingly, is to project, as closely aspresent limitations of knowledge permit, the course of the demand for petroleumin the United States over the next ten years.
At first, the problem of estimating the future of a demand as complex asthat for petroleum might appear insoluble. Fortunately, however, there areseveral scientific methods of approaching the problem, centering around a studyof rates of industrial growth, which lend considerable hope that therequirements of the immediate future in this field may be approximated withsufficient closeness to have practical value as a basis of action.

Growth of Petroleum Demand
The demand for crude petroleum is the resultant of the demands for theproducts made jointly from this substance - gasoline, kerosene, gas and fueloil, and lubricating oils.
AIME 068–66
Canadian Oil Reserves
Authors: Arnold Ralph , English Walter A. 
Published: June 2014

Though production began in Canada only a short time after the discovery ofoil in the United States, it has never attained large proportions, and if wewere to judge entirely by the past the reserves of Canada would be put at avery low figure. There are only two areas from which oil is marketed at thepresent time; one, the old district around Petrolia in southern Ontario, andthe other is the small Sheep Creek field near Calgary in Alberta. The formerdistrict has produced between 200,000 and 800,000 bb1. annually for the past 40years, recent figures being near the minimum amount. Sheep Creek has producedabout 12,000 bb1. annually for the past five years. The known reserves inproved territory in each of these fields are exceedingly small, when consideredin terms of world reserves.
The chief hope of Canada for reserves of considerable magnitude lies in thewestern provinces. Sedimentary rocks similar to those in the productive fieldsof the United States occupy thousands of square miles in the western provinces, so that it seems likely that somewhere within this great area the peculiarconditions necessary for the presence of oil pools will be found. Prospectingis being carried on energetically by several large companies, as well as bymany independents. The Dominion Government, which controls most of the publiclands, is pursuing a fairly liberal policy toward the prospector, which shouldstimulate wildcatting, although the province of British Columbia, whichcontrols public lands within that province, is at present unwilling to giveadequate encouragement to make wildcatting attractive.
As there is really no assurance that any productive pools will be found inwestern Canada, the estimates of reserves are subject to a wide possibility oferror. In making estimates, the various areas within which geologic conditionsare more or less uniform are discussed separately; the estimates given for eacharea are not given with the idea that there is a reasonable probability oftheir eventually proving to be correct.
AIME 068–67
Centrifugal Removal of Wax from Petroleum Lubricating Oils
Authors: Jones Leo D. 
Published: June 2014

The use of the centrifuge for dewaxing lubricating oils grew out of theeffort to secure better results than had been attained by the common ?coldsettling? process. This process was the only known method for dewaxing steamrefined cylinder stock (600? F. fire test), the product known as ?bright stock?being commonly used for building up ?pressed,? i.e., dewaxed neutrals of, say,200-sec. viscosity to a higher value. The process consisted of mixing thecylinder stock with approximately one and one-half times its volume of naphtha, heating to dissolve completely all the oil and wax and then slowly chilling toabout 15? F. in large insulated tanks. This caused the wax to precipitate. Itwas allowed to settle out by gravity. The supernatant liquid was then drawn offand the naphtha distilled off, leaving a still residue of bright stock. Thesediment from the settling, of a slushy nature, was withdrawn. After removingthe naphtha by distillation the residue was petrolatum. At some point in theprocess, preferably after the dilution but before chilling, the mixture wasdecolored by percolation through fuller's earth.
The finished bright stock produced by this process had a cold test of about50? F. Efforts to improve this by chilling to a lower temperature resulted in aconsiderable reduction in yield, and increased uncertainty of settling. Evenwhen chilling to 15? F. it was not uncommon to find that after a week's waitinga tank had not settled. It was then necessary to heat and rechill. Thisuncertainty was a serious problem; in one case a refinery superintendent hadmen riveters hold pneumatic hammers against the tank for hours, hoping thus tocause agglomeration and settling of the wax. Yields of bright stock above 70per cent. were uncommon.

History of Centrifugal Application
It is not surprising, therefore, that many attempts were made to improveupon the results obtained by cold settling.
AIME 070–60
Oil Structure Investigation by Diamond Core Drills
Authors: Longyear R.D. , Donovan P.V. 
Published: June 2014

The use of the diamond drill as a means of securing information onstructural geology in connection with oil exploration was advocated for severalyears prior to actual field trial. As far as we know George E. Burton, a memberof the Institute, and at present geologist for the Humble Oil &RefiningCo., was the first one to recommend it in a published article. Early in 1917Mr. Burton, then assistant director of the Oklahoma Geological Survey, prepareda brief bulletin on this subject for the survey and it was issued as one of thesurvey publications in July, 1917. Data secured from diamond drill holes boredfor coal had been used in the study and investigation of possible oilstructures in the State of Illinois and among the earliest trials of diamonddrilling as a guide to oil exploration was certain work carried out under thedirection of the Illinois State Survey about 1920, F. W. DeWolfe then beingState geologist.
The Mid-Continent field soon recognized the value of this agency and inNovember, 1920, the first work of the kind in the Mid-Continent districts wasstarted in Kay County, Oklahoma. This form of investigation has become ofincreasing importance until now approximately 50 diamond drills are inoperation in various parts of North America working solely on the problem offurnishing structural data where surface exposures are absent or inconclusive.The greater part of these drills are at present in Northern Oklahoma andSouthern Kansas, although Texas and the Rocky Mountain region have seen a fairshare of diamond core drilling.
Drilling is usually carried out in a regular pattern, holes being located atevery section corner or every other section corner. Shorter intervals aresometimes necessary for close work. Frequently several drills will be placed onone block of leases in order to secure quickly the desired information.Drilling is carried to whatever depth is required to form a basis forreasonably accurate correlation. In most districts this means holes less than600 ft. deep.
Increasing the Extraction of Oil by Water Flooding
Authors: Umpleby Joseph B. 
Published: June 2014

Interest attaches to water flooding as a means of increasing the extractionof oil because of its remarkable success in the Bradford field in the northwestpart of Pennsylvania, and the possibility of application in otherlocalities.
The constantly increasing demand for petroleum products and the increasingdifficulty of finding new oil fields is directing serious attention to the oilleft in the ground at the time when wells producing by normal methods haveapproached their economic limit. In Germany mining operations have proved thatproduction by wells over a period of 50 to 75 years has only recovered from 13to 15 per cent of the oil in the sand. In the Bradford field of Pennsylvania itis fairly well established that normal production over a period of 50 yearsrecovered only about 3000 bbl. an acre out of a total oil content of at least30,000 bbl. Similarly for many other fields it is estimated that recovery byusual methods runs from 10 to 40 per cent of the oil content of the sand. Inexceptional cases recovery may be higher, as in areas where edge waterencroaches rapidly or in open sands where gas pressure is unusually high andconserved by slow development. This unrecovered oil constitutes a tremendousreserve of petroleum in areas where conditions of drilling, sand, and water arewell known, and where the facilities for gathering and marketing the productionare already established.
The means of recovering a portion of the oil remaining in old fields fallsinto three principal groups - mining, air flooding and water flooding. Miningis being successfully carried on in two fields in Germany, air flooding hasbeen found profitable in about 15 localities in the United States, and waterflooding is a proven success in the Bradford field of Pennsylvania and theBolivar field of New York. Only water flooding will be considered in this paperwhich is devoted primarily to what is actually being done in the Bradford fieldand the technique that surrounds it.
Influence of Submergence on the Efficiency of the Oil-well Plunger Pump
Authors: Uren L.C. , Collins V.J. , Sargent S.B. 
Published: June 2014

Among the several variables which determine the efficiency of the type ofplunger pump commonly used in oil-well service, the submergence of the pumpbelow the fluid surface in the well plays an important part. Wheninsufficiently submerged, the pump will deliver less than half of itstheoretical plunger displacement. In many instances, it seems probable thatwells yield only half of what they are capable of producing, because theoperator fails to maintain a suitable submergence on the pump.
This paper describes the conditions, within and surrounding the pump whilein operation in the well, which influence the effect of submergence on pumping efficiency; it presents the results of an experimental study designed todisclose the quantitative effect of submergence on pump efficiency; and offers conclusions which indicate the approximate submergence desirable and emphasizethe necessity for a knowledge of operating fluid levels within pumpingwells.
Theoretical Conceptions of Effects of Factors Causing Variation of PumpEfficiency With Submergence
Unless immersed in the well fluid, the plunger pump is dependent for itssupply of oil upon the suction effect of the ascending plunger, which isinadequate to draw a supply of oil sufficient to fill the working barrel, through the restricted orifices at the standing valve and lower plunger nut.The static head developed within the oil at the level of the standing valve, byample submergence, is needed.
Water Shut-off Methods in the Salt Creek Field
Authors: Armstrong Ray O. , Rader C.M. 
Published: June 2014

To date the important water shut-off problem in the Salt Creek field hasconsisted of the protection of the Second Wall Creek sand from water occurringin the overlying First Wall Creek sand. This shut-off is the only oneconsidered in detail in this paper.
Since a shale and sandy shale interval, averaging 260 ft. in thickness, liesbetween the First and Second Wall Creek sands, the water shut-off has neverbeen mechanically difficult. The larger portion of the engineering effort onthe part of Department of the Interior engineers and those of operatingcompanies in connection with this water problem has been towards thedevelopment of adequate protection to the oil horizons with a minimum cost intime, labor and material.
From August, 1917, when the first Second Wall Creek well was completed, until March, 1921, when Circular No. 2 of the Petroleum Division of the U.S.Bureau of Mines outlining the approved method of drilling Second Wall Creekwells in the Salt Creek field, went into effect, no standardized method ofshutting off First Wall Creek water was in use. During this period 98 SecondWall Creek wells were completed. Records on these earlier wells are, in manycases, incomplete, but on inspection of 42 logs, selected because of theirapparent accuracy and because they represent all characteristic conditionsoutside the First Wall Creek oil area, we find the following conditions:
Twenty-four jobs were formation shut-offs. Of these nine, or 37 1/2 percent, have required repairs since completion. Eighteen were cemented, only oneof which, or 5 1/2 per cent has required repairs since completion. Of the 18which were cemented four, or 22 per cent required second jobs, as a shut-offwas not effected in the first instance. This percentage of first cementfailures has decreased materially with an increasing understanding of cementingmethods.
The Ranney Process of Mining Oil
Authors: Ranney Leo 
Published: June 2014

The Ranney process contemplates the sinking of a shaft, a manway and ahoisting compartment, all to the region of the oil sand. This shaft stops ontop of the cap rock above the sand, or it passes through the upper cap rock, through the sand and through the lower cap rock, below the sand. From thebottom of the shaft manway tunnels are driven on top of the upper cap rock orjust below the lower cap rock-never in the oil sand. Eventually a plat of thesecriss-crossing tunnels may resemble streets in a city. Each tunnel contains apipe line.
At intervals of say 10 ft. in each tunnel, a 3-in. hole is drilled in thecap rock almost to the oil sand. A 2-in. nipple is sealed in each hole by anair-tight seal. (See Figs. 1 and 2.) A cross is screwed on the outer end of thenipple, and the pipe line is screwed horizontally into the cross on two sides.In this way each oil-receiving nipple becomes a collecting branch of the pipeline. Then a rock drill is inserted through the cross into the sealed-in oilnipple, with which drill a hole is made into the oil sand. When production issecured the drill is withdrawn, an iron plug is screwed into the fourth hole ofthe cross and the simplest form of "mine well" is complete. (See Fig.3.) If artificial forces of expulsion are employed, they may be applied to andthrough the pipe line to all nipples and all holes in the sand.
Some Analytical Principles Covering Oil Recovery by Forced Drive
Authors: Herold Stanley C. 
Published: June 2014

This paper covers "an ideal situation with a formation horizontal, uniform thickness of sand, perfectly homogeneous texture and containing oilwith gas in solution with no water, throughout a definite, although undefined, lateral extent," and outlines fully an analytical method covering each ofthe following problems: Ideal drainage area, application of forced drive toexhausted wells, recovery of oil from an elliptical area, the systems offlooding in common use as applied to such area, and the method of determiningthe area of the elliptical non-drained space, and the application of this tothe determination of whether it is less costly to space wells closely or applygreater pressure.
J. B. Umpleby, Oklahoma City, Okla. (written discussion).Mr. Herold? sanalysis of principles concerning oil recovery by forced drive is timely andthe conclusions follow logically from the premises taken. I doubt, however, ifthe method of elliptical areas can be applied in fields that have alreadyyielded a large amount of oil. The method seems to imply a saturated reservoirrock, the result of pressure being to develop stress in the fluid withoutbodily movement except as localized by producing wells. Under these conditionsthere will be undrained areas as indicated in his Fig. 4. Will the same area beundrained if saturation is incomplete? It is at this point where pressures fromopposite directions first meet, causing a pressure gradient outward toward anoil well in staggered position. The amount of oil leaving this area will dependon the steepness of the pressure gradient, the porosity, and the time elapsingbefore fluid saturation is reached in the triangle between wells. When thereservoir rock between first and second-line wells becomes saturated, movementwill doubtless he in elliptical areas but observations at Bradford lead me tobelieve that more than half the total migration of oil in any particular areatakes place before it becomes fully saturated.
Core Studies of the Second Sand of the Venango Group, from Oil City, Pa.
Authors: Fettke Charles R. 
Published: June 2014

The oil fields of Western Pennsylvania have reached that stage in theirdevelopment history in which the rejuvenation of depleted properties, by suchmethods as compressed air, water flooding, etc., offers a much more attractiveproposition to capital than the search for new pools in undeveloped territory.In order to apply such methods intelligently, a more detailed knowledge of thecharacter of the oil sands, than has heretofore been deemed necessary, ishighly essential. Such information can be obtained to best advantage with thecore drill. Cores yield data that cannot possibly be obtained otherwise, evenby the most careful study of cuttings taken by the ordinary cable-toolmethod.
The Brundred Oil Corp., of Oil City, Pa., the pioneer in the introduction ofcompressed air for the restoration of production on depleted properties inPennsylvania, recently completed a diamond-drill test of the Second Sand of theVenango Group, on one of its properties in Cornplanter township, about a milenorthwest of Oil City. Through the courtesy of H. D. Brown and W. J. Brundred, officials of the company, the cores were made available to the writer for studyin connection with an investigation of the oil and gas sands of the State forthe Pennsylvania Geological Survey.

Drilling Equipment
A Sullivan-type diamond drill, with double-tube core barrel, and capable oftaking a core 2 1/4 in. in diameter, was used. The wells were first drilledwith cable tools to within 5 or 10 ft. of the top of the sand, as calculatedfrom the logs of nearby wells, using a single string of 5 5/8-in. casing toshut off the water from upper horizons. A string of 4 1/4-in. casing was thenset on the bottom of the hole and the diamond drilling was done through it inorder to prevent excessive vibration of the drill rods. The 5 or 10 ft. ofshale above the sand permitted the starting of a straight hole with the coredrill before the sand was penetrated. Core losses in the sand were practicallynegligible.
Improved Drilling and Production Methods in the Gulf Coast Field
Authors: Russell J.H. 
Published: June 2014

The great number of wells being drilled in the Gulf Coast creates a greatdemand for and an opportunity to improve the methods of drilling wells and ofproducing oil from them. Some improvements have been made, but in the presentstrenuous drilling campaign at Spindle top, the quickest methods of drillingand completing wells are much too slow. Therefore, not a great deal of thoughthas been given to new methods.
However, one can not help but compare the method and equipment used in thepresent-day drilling campaign at Spindletop with those of 1901. The differencesin equipment and methods are staggering and the present-day operators canhardly imagine how the old operators ever were able to drill a well. The"old timers" explain the reason as being that "Men were men inthose days and not much machinery was necessary." Yet the development in 25years of thought and study has brought about a great improvement in equipmentand in methods.
I believe there has been a great deal more thought given to the developmentand improvement of drilling equipment and methods and to the completion ofwells than has been given to the actual production operations.

Drilling Methods and Equipment
The greatest improvement that has been made in the methods of drilling andcompleting wells in the Gulf Coast is in the rotary equipment machinery used indrilling. Equipment more suitable and applicable to the duty imposed indrilling wells has been and is being steadily developed. The operators are nowstudying and are beginning to find out just what work, what duty the machinerywill have to perform before a well can be drilled to the various depths in thequickest time and in the best possible manner.
I think more than ever before the oil operator is making "carefuldiagnosis of drilling conditions," such as the character of formations tobe drilled, the depth of the hole, the size of the hole, the manner and sizesof pipe to be set and the time required to drill to certain depths.
Approved Drilling and Production Practice in Oklahoma and Kansas
Authors: McWilliams J.R. 
Published: June 2014

The task of recovering most of the contents of an oil and gas reservoireconomically presents many and varied problems. In order to attemptintelligently a solution of these problems, an understanding of fundamentalphysical laws is essential. As the pertinent facts needed in applying theselaws to recovery problems are not readily obtainable, observation must be madeand the data tabulated. Here, good judgment must be exercised, for at best theinformation is meager.
The engineer is well fitted to undertake the task of solving this problem.In my opinion, the decision on the part of some production executives to allowthe engineer to cope with the oil recovery situation and other problems is anoutstanding example of improvement in production methods. The executive headmust make this decision or the qualified engineer will be working under asevere handicap with the present system of supervising the production of oiland gas.
A qualified engineer should have not only the required technical trainingbut also enough field experience to enable him to understand the difficultiesencountered in producing oil and gas. Such a man tactfully cooperating with thepractical oil man can greatly improve present methods of oil recovery. Therealization that Nature's forces have not been efficiently controlled in pastrecovery of petroleum deposits has recently brought distinct improvement inproduction methods.
Papers are to be presented at this meeting discussing in detail improvedmethods of conserving gas in both flowing and pumping wells, and also methodsof lifting oil after Nature's supply of gas has proved inadequate. Theapplication of back-pressure to producing oil wells has not, to my knowledge, been extensively applied in Oklahoma or Kansas up to the present time. Most ofthe flowing wells are allowed to flow through the casing until the rockpressure has been dissipated. However, some flowing wells have been tubedbefore the well stopped flowing through the casing. Recording pressure-gagescan be installed to study well performance.