bluuebunny/crossref_metadata_2025_split huggingface dataset:
Calculated Recoveries by Cycling from a Retrograde Reservoir of Variable Permeability
Authors: Standing M.B. , Lindblad E.N. , Parsons R.L. 
Published: June 2014

Abstract
The recovery of the heavier components from a gas cap or retrograde pool isshown to be the greatest when the sand is cycled with a dry gas at a lowpressure. This conclusion is in direct opposition to the belief that the mostefficient production program is pressure maintenance and cycling at or near thedew point.
The results are calculated from:constant volume, variable compositionpressure-volume-temperature tests on a mixture of trap gas and liquid from aproducing well;published equilibrium constant data and the measuredcomposition of the dew-point material; andthe fact that in a sand sectionof homogeneous permeability, injected gas displaces reservoir gas nearlyquantitatively.
The results are based on the simplifying assumption that variable permeabilitysystems may be defined by the ratio of two statistical parameters, and that gasinjected into an actual sand will behave as though the sand were composed ofmany layers, each of constant permeability.

Introduction
Pressure decline in gas-condensate type reservoirs is accompanied by theformation of a liquid phase throughout the reservoir. Over the past ten yearsthe processing of the material from these types of reservoirs for the heavierhydrocarbon components and the return of the light fraction to the reservoir("cycling") has become increasingly popular. It has often been stated that thepurpose of such a program is to prevent the loss of the retrograde liquid phaseformed in the reservoir.
The purpose of this paper is to present the results of laboratory tests andcomputations concerned with several possible methods of producing a gas cap orcondensate type of reservoir.
The results show that the recovery of heavier hydrocarbons for this type ofreservoir is not a maximum under conditions of cycling at or near the dew-pointpressure. Instead, variations in permeability and the ability of the dryinjected gas to revaporize condensate, point to cycling at a considerablyreduced pressure as the optimum production-method. In addition the papersuggests a way of evaluating sands for their permeability variation.
The calculations presented in the following sections of the paper are in termsof the production of the butanes and heavier fraction from the gas gap of afield which had an original pressure of approximately 3000 psi.
T.P. 2200
Significance of World Petroleum Production Trends
Authors: Baker Warren  L. , Logan L.J. 
Published: June 2014

Abstract
By 1950 or soon thereafter facilities will be available in foreign countriesfor the production, transportation, and refining of about 4,305,000 bbl per dayof crude oil-a volume not far short of current United States output. This isindicated by announced plans for foreign expansion, some of the work beingalready under way. The projected potential production is about 1,500,000 bblper day or 50 pct above the record-setting foreign production of 2,810,000 bbldaily in 1946. The scheduled new foreign facilities are equivalent to almostone third of the present facilities of the United States.
Fears that so much additional foreign oil may flood world markets and disruptthe domestic industry of the United States are not justified. The projectedforeign expansion apparently has been planned on a sound business basis, withcareful consideration of the world's actual need for all the projectedadditional production. Materially increased world demand for petroleum promisesto absorb the increased supplies without ill effect upon the domestic industry.Even by applying conservative estimates of both foreign and domestic demand, itis indicated that world requirements can absorb the projected larger foreignoutput and still permit continued increase in United States production. Worlddemand would have to increase only 5.7 pct per year in the 1947 to 1950 periodto absorb the prospective supply. Such an increase may be conservativelyprojected, in view of past and current trends.

Introduction
Recent announcements of plans for expanding petroleum facilities in the MiddleEast and Venezuela foreshadow an unusually sharp increase in foreign productionin the immediate future. Therefore, the next few years will bring far-reachingchanges in world petroleum affairs, with foreign petroleum production and otheractivities assuming much greater importance than formerly.
Tabulation of figures on development already under way or planned indicatesthat in the next several years facilities will be available for producing, transporting and refining twice the prewar production of foreign fields andabout 50 pct or nearly 1,500,000 bbl a day above their record-level output of1946.
To say that foreign fields may be producing such an enlarged quantity by 1950is, of course, a statement of great significance to everyone connected with theoil industry and especially to those of the American petroleum industry. Aproduction of 1,500,000 bbl daily is equal to the combined yield of the statesof Oklahoma, Kansas, Illinois, Louisiana, Arkansas, Mississippi and New Mexico, This means that within the next several years foreign petroleum facilities willundergo a new expansion equivalent to one third of the present facilities ofthe United States.
To think of such an expansion in foreign production is to raise at this meetingthe question of what this prospective foreign development means for the UnitedStates, the American petroleum industry in general, and the American engineerand technologist in particular.
T.P. 2228
Planning a Multiple Well Directional Drilling Program for Offshore Locations
Authors: Jackson John G. , Murdoch J.B. 
Published: June 2014

Abstract
The many mechanical, geological, and economic factors which influence theplanning of a directional drilling program are thoroughly discussed andanalyzed. It is demonstrated that the planning of a directionally drilledmultiple-well artificial island location is a complicated undertaking and thatit is imperative that complete planning and engineering analysis be undertakenbefore the program is started. Complete planning is profitable because all ofthe factors influencing the directional work are in general interrelated andmany time compromises have to be made before a harmonious program results.
The engineering control necessary to accomplish a complicated directionaldrilling program is outlined. Various means by which engineering control can beincreased, such as cylinder drilling specifications, are given. A hypotheticalexample is developed for a complete offshore artificial island of ten wells todemonstrate the more important factors involved in the planning. Included withthis example are special charts and tables which make more rapid the draftingof directional drilling proposals and maps.

Introduction
A petroleum engineer must consider many and varied factors when planning along range directional drilling program for an offshore or inaccessiblelocation on an oil structure. The basic principles of directional drillingplanning and operation must be reconciled with his company's drillingpractices, and frequently special concessions to standard drilling andproduction practices should be made. The field techniques and tools used indirectional drilling are well known and widely used, but the deliberate, careful planning of a complete directional program is in the main a recentinnovation. This development, plus the increased demand for oil resources andthe consequent exploitation of inaccessible structures and offshore locations, has placed this problem before many engineering departments for the firsttime.
Directional drilling programs of a very complex and difficult nature havebeen successfully carried out in the Mid-Continent and Pacific Coast regions.The planning itself of a directional drilling project, however, has not had thecareful analysis it deserves and we can reasonably expect widespread futureprogress along these lines. Data and experience gained in these programs by thedirectional drilling service companies and the oil producers have been studiedwith the objective of giving the engineer a better conception of the factorswhich govern the various steps in planning a series of directional wells. Thenewest engineering procedures are the result of recent careful analysis ofyears of directional drilling work accomplished under the supervision ofdirectional drilling service companies working with the oil companies.
T.P. 2325
Oil-shale Mining
Authors: Ertl Tell 
Published: June 2014

Abstract
The term oil shale is defined. Foreign oil shale developments are outlinedbriefly. The richest and most extensive oil-shale deposits in the United Stateslie in western Colorado. The Bureau of Mines is opening two adjacent areas forunderground mining in western Colorado. From the first area the oil shale ismined selectively as required by the retorting plant. The second area is beingdeveloped as a unit of a full scale oil-shale mine to ascertain the mostpractical methods of mining oil shale and to determine costs. In both of thesemining areas, research will be carried on to develop new and improved practicesfor mining oil shale.

Introduction
Oil shale is a sedimentary rock containing a solid mineraloid of indefinitecomposition known as kerogen. On heating oil shale, the kerogen undergoesthermal decomposition and some of the vapor products of the decomposition canbe condensed as shale oil. Oil from shale can be a major source of liquid fuelssince extensive deposits of oil shale are known to exist throughout the world.The United States considers the establishment of an oil-shale industry onlywhen doubt exists of the adequacy of the domestic supply of crudepetroleum.
On the other hand, oil shale is not strange to foreign oil men. The industryis an old one in other parts of the world. The French industry has been inexistence since 1838, the Scottish since 1859, the Australian since 1860, theEstonian and Swedish industries since World War I, and the Manchurian industrysince 1929.
The most highly exploited oil-shale deposits are the Carboniferous shales ofScotland. About 20 seams ranging from 4 to 12 ft in thickness are worked. Theyield during recent years in Scotland has been 18 to 25 gal of shale oil perton, from 3,000,000 tons per year. The French and Swedish oil-shale depositsare of lower grade than the Scottish. The Estonian oil shale deposits are 7 ftthick, and the oil yield averages 50 gal per ton. Over 1,000,000 tons are minedeach year, half of which is used directly as fuel to substitute for coal andthe other half is used for the production of oil.
T.P. 2359
The S.P. Log: Theoretical Analysis and Principles of Interpretation
Authors: Doll H.G. 
Published: June 2014

Abstract
The S.P. log is shown to be a measurement of the potential drop along thedrill hole, caused by ohmic effect in the mud. The notion of static S.P. isbrought forward, and its relation to the S.P. log is discussed. Other factorsinfluencing the shape and amplitude of the log are considered; attention isgiven to conditions encountered in practice. Numerous figures are givenillustrating graphically the results; these figures are of particular interestfor comparison with field examples.
The S.P. log, although indicating permeability, is not an absolutemeasurement of permeability, nor of porosity, of the formations traversed by adrill hole. It is affected by several parameters, such as resistivity offormations and mud, thickness of formations, and others, which should beappraised carefully. Simple rules have been established for a betterdistinction of the boundaries of permeable sections, particularly in difficultcases, such as those encountered in highly resistive formations. A systematicapplication of the established principles will assist in obtaining moreinformation from the S.P. log than was possible thus far; for instance, underfavorable conditions, presence of oil may be detected, or amount of shale insands may be estimated.

Introduction
The S.P. log, or spontaneous potential log, has been known and widely usedduring the last 15 years for the location of permeable beds traversed by drillholes.
In electrical logging practice, the S.P. log is shown on the left hand sidetrack of the record (as may be seen in later examples) where it can be easilycorrelated and interpreted with the resistivity curves located to the right.Usually, the S.P. log consists of a base line, more or less straight, havingexcursions or "peaks" to the left. The base line frequently has beenfound to correspond to impervious beds, while the peaks are usually foundopposite permeable strata.
Measurements which will indicate positively the presence of permeability inthe formations, and which will give accurately the boundaries of the permeablezones, are of great importance in oil-field practice. Thus far, the S.P. log isthe best approach to such determinations; unfortunately, its interpretation isnot always evident.
With respect to the base line of the S.P. log, it may be noticed that thisline is not always at a definite location on the chart. Sometimes it may shiftabruptly, while other times a gradual drift is apparent.
As far as the peaks are concerned, their shape is not uniform; some arerounded while others are sharp. Also, from other data, it may be found thatoccasionally the peaks extend appreciably beyond the boundaries of permeablezones into zones which are not everywhere permeable.
A comparison with permeability measurements made on cores has oftenconfirmed that there was no definite correspondence between the magnitudes ofthe peaks and the permeability values.
T.P. 2463
Effect of Antifreeze Agents on the Formation of Hydrogen Sulphide Hydrate
Authors: Bond Donald C. , Russell Nelson B. 
Published: June 2014

Abstract
The effects of various antifreeze agents on the formation of hydrogensulphide hydrate have been studied. On a molar basis the relative lowering ofTM (the maximum temperature at which solid hydrogen sulphide hydrate can existin equilibrium with the given solution) for the various agents is: sodiumchloride 1.00, calcium chloride 1.71, methyl alcohol 0.57, ethyl alcohol 0.68, ethylene glycol 0.73, diethylene glycol 0.73, sucrose 0.87, dextrose 0.71. On aweight basis the relative lowering of TM is: sodium chloride 1.00, calciumchloride 0.91, methyl alcohol 1.08, ethyl alcohol 0.89, ethylene glycol 0.69, diethylene glycol 0.41, dextrose 0.23, and sucrose 0.15.

Introduction
The solid hydrate of hydrogen sulphide, H2S?6H2O1, is in equilibrium withwater and liquid hydrogen sulphide at 85?F at a partial pressure of hydrogensulphide approximately equal to the vapor pressure of hydrogen sulphide at thattemperature. At temperatures below 85?F, in the presence of excess hydrogensulphide (greater than the amount required to react with the water present) thehydrate is in equilibrium with liquid hydrogen sulphide at approximately thevapor pressure of hydrogen sulphide.
In the presence of excess water, the solid hydrate is in equilibrium withliquid water, containing dissolved hydrogen sulphide, at a pressure lower thanthe vapor pressure of liquid hydrogen sulphide at the same temperature. Thelower the temperature, the greater the difference between the decompositionpressure of the hydrate and the vapor pressure of liquid hydrogen sulphide atthat temperature.
Conditions conducive to the formation of solid hydrogen sulphide hydrate mayexist in wells producing a gas containing a high percentage of hydrogensulphide under high pressure, or in the lead lines from such wells. This papergives the results of tests made with various antifreeze agents which might beuseful in decomposing the hydrate or in preventing the formation of the hydrateof hydrogen sulphide.

Apparatus
Fig I shows a diagram of the apparatus used. The sample under observationwas contained in a glass tube 34 cm long, having a 6 mm id and a wall thicknessof 2.5 mm. The lower end of this tube was closed with a plug of butyl rubber.The upper end of the tube was connected to a diaphragm gauge, with a stainlesssteel diaphragm, a manometer, a vacuum pump, and a cylinder of hydrogensulphide.
The tube was held nearly horizontal, with the liquid resting along the lowerside of the tube. It was found that when the tube was held in a verticalposition, it broke with explosive violence as soon as it became filled withsolid hydrate. Presumably this was caused by the expansion which occurred onsolidification of the hydrate. The difficulty disappeared when the tube washeld in an inclined position during the tests.
T.P. 2450
Lance Creek Sundance Reservoir Performance - A Unitized Pressure-Maintenance Project
Authors: Elkins Lincoln F. , French R.W. , Glenn Wayne E. 
Published: June 2014

Abstract
The Lance Creek Sun dance reservoir provides a case history of 10 yearsperformance of a reservoir in which unit operation has permitted effectiveutilization of gravity drainage augmented by primary pressure control withinjection of gas in to top structural wells. Detailed performance of thereservoir is presented by means of maps of well status, reservoir pressure, individual well recovery, etc., and by pool-performance charts. Analysis ofreservoir performance indicates only minor water encroachment, so that gravity, injected gas, and expansion of gas are the main oil-expulsive agents.
A simplified theory of regional drainage of oil from upstructure location todownstructure location due to gravity is presented and checked by means of comparison of "reservoir" permeability and"well" permeability from the pool performance. Good order of magnitudeagreement was obtained.
Individual well performance and overall reservoir performance indicatepossibility that maintenance of pressure makes ineffective those parts of thereservoir in which permeability is too low to permit effective drainage of oilby action of gravity. Oil from these parts can be recovered only when pressureis reduced locally by selective withdrawal or when overall reservoir pressureis finally reduced.

Introduction
The Lance Creek oil field, Townships 35 and 36N, Range 65W, Niobrara County, Wyoming, was discovered in October 1918, when Ohio Well No. State I wascompleted in the Dakota horizon at a depth of 3665 ft, with an initialproduction of 1500 bbl daily.
T.P. 2401
A Note on the Application of the Capillary Pressure Method for the Determination of Oil Recovery
Authors: Rose Walter 
Published: June 2014

Experimentation which measures differences in pressure across the interfacesof immiscible fluids in the interstitial spaces of porous media may be termed"capillary pressure experimentation". In the literature of petroleumtechnology since 1941 there have appeared twelve papers popularizing capillarypressure concepts and developing applications of these concepts for thesolution of problems of practical reservoir engineering importance, such as thedetermination of connate water, fluid distribution in transition zones, reservoir rock textural properties, and oil recovery from petroleumreservoirs.
Although a review of the literature would be justified at this time in order toreconcile the conflicting viewpoints which are contained in the cited papers, the object of this note will be of more limited scope. It is believed that therecent paper of Muskat calls sufficient attention to many of the uncertaintieswhich arise upon examination of the published literature, such that untilsatisfactory counter-proposals can be made it will serve our purpose only tomention some other like uncertainties. This will emphasize further the needconfronting petroleum technologists to reconsider and reformulate theapplication possibilities of capillary pressure experimentation. In particular, I suggest that we examine the thesis that capillary pressure experimentation asabove defined can lead to measurements reflecting the recovery of oil frompetroleum reservoirs, as was proposed first by Amyx and Yuster and was firstreduced to practice by the experimentation of Welge. In fact, I shall dealexclusively with the Welge papers since it is the principle one on this subjectwhich has appeared to date. I shall attempt to show that the possibility ofdescribing oil recovery features in terms of capillary pressure phenomena hasnot been established entirely.
The Welge paper was a pioneering effort to evaluate this recovery applicationpossibility. P. P. Reichertz comments on the Welge paper state that non-wettingphase discontinuities are developed occasionally in the Welge experiment, andrestate Muskat's argument that discontinuous fluid elements (partiallysaturating the interstices of porous media which are elsewhere saturated withsome other immiscible phase or phases) are not subject to the requirements ofhydrostatic equilibrium. It is the purpose of my comment to show that it isunnecessary to make Reichertz' postulation regarding nonwetting phasediscontinuities (however valid) when it is desired to criticize Welge'stheoretical treatment of his problem. It can be shown that Welge's method ofmeasuring values for "capillary pressure" is invalid in many instancesof application, such that his reported curves of capillary pressure versusfluid saturation often have no physical meaning, even throughout the intervalof fluid saturation where it might be otherwise suspected that no phasediscontinuities occur.