bluuebunny/crossref_metadata_2025_split huggingface dataset:
Review of Cycling Operations in the La Gloria Field
Authors: Justice W.H. 
Published: April 2012

Purpose
Cycling operations have been successfully conducted in the La Gloria Zone foreight years. The cycling of this zone is now virtually completed. It isproposed that this report shall review the cycling operations of this reservoirso that the industry can more accurately evaluate the cycling process as aproduction method.

Introduction
The La Gloria project is one of the largest cycling operations in the Stateof Texas. The gas rights in the field are unitized in three operating units. Bymutual agreement Magnolia Petroleum is the designated operator of the projectfor the 12 operators owning the gas rights. The La Gloria Corp. is the ownerand operator of the cycling plant. The development and operation of the fieldare under the direction of an Operators Committee comprised of a representativeof each operator. The Operators Committee is assisted by an Engineering andGeological Sub-Committee.
The La Gloria gas field is situated approximately three miles north ofFalfurrias, Tex., and lies principally in the extreme south end of Jim WellsCounty, with its outer limits extending into the north end of Brookes County, Tex. It is a simple elliptically-shaped dome which has a closure of 350'Ft. Thefield encompasses a surface area of 5,500 acres. The gas reserves are found in20 major sand zones lying in the lower Frio formation and Transition Zone ofthe Upper Vicksburg formation. Approximately 40 gas wells have been drilled inexploring and developing the gas reserves of the field.

Discussion
The La Gloria sand occurs in the lower Frio formation at a depth of 6,515 ft atthe crest of the structure. The average sand thickness for this zone is 32 ft.The reservoir initially had a gas column of 125 ft and did not have an oilcolumn. The sand has an average porosity of 22.2 per cent and an averagepermeability of 521 MD. The productive area of this zone is 2,680 acres. Theoriginal bottom hole pressure was 3,470 psia and the formation temperature is203?F. The average percentage connate water in the reservoir space has beenestimated at 20 per cent.
T.P. 2952
Laboratory Measurements of Relative Permeability
Authors: Osoba J.S. , Richardson J.G. , Kerver J.K. , Hafford J.A. , Blair P.M. 
Published: April 2012

Abstract
This paper presents the results of laboratory measurements of relativepermeabilities to oil and gas on small core samples of reservoir rock by fivemethods, and describes the influences of such factors as boundary effect, hysteresis, and rate upon these measurements. The five methods used were the"Penn State," the "single core dynamic," the "gasdrive," the "stationary liquid," and the "Hassler"techniques.
In those methods in which the results are subject to error because of theboundary effect, the error may be minimized by the use of high rates of flow.In order to avoid complexities introduced by hysteresis, it is necessary toapproach each saturation unidirectionally. Observed deviations of relativepermeabilities with rate can be explained as a manifestation of the boundaryeffect, and disappear as the boundary effect vanishes.
The results indicate that all five methods yield essentially the samerelative permeabilities to gas. Of the four methods applicable to thedetermination of relative permeability to oil, three, the Penn State, singlecore dynamic, and gas drive, gave relative permeabilities to oil which were inclose agreement. The Hassler method gave relative permeabilities to oil whichwere consistently lower than the results obtained by the other methods.

Introduction
The relationship between the effective permeability of a reservoir rock toeach of the fluids flowing through it and the corresponding fluid saturation isan important characteristic of the reservoir rock. Knowledge of thischaracteristic is and gas reservoirs and of the ultimate recovery to beexpected extremely important in the prediction of the behavior of oil undervarious operating conditions. These effective permeabilities are usuallyexpressed as the "relative permeability" to a fluid phase, defined asthe ratio of the effective permeability to the permeability of the rock to asingle phase at 100 per cent saturation.
Relative permeability-saturation relations are not the same for all kinds ofreservoir rock, but may vary from formation to formation, and within thedifferent portions of a heterogeneous formation. In studying the performance ofa specific reservoir, it is necessary, then, that the relative permeabilitycharacteristics of the individual portions of the reservoir be measured. Thesemeasurements may be made in the laboratory on small core samples from thereservoir.
Various techniques have been proposed for the measurement in the laboratoryof relative permeability-saturation relations. In varying degree, difficultiesattend the use of all of the methods which have been proposed. It is thepurpose of this paper to discuss the factors which influence the measurement ofrelative permeability, the difficulties encountered in several methods, and topresent comparative results obtained by the use of various techniques.
T.P. 3020
An Analysis and the Control of Lost Circulation
Authors: Howard George C. , Scott P.P. 
Published: April 2012

Abstract
During the drilling of wells, fractures which are created or widened bydrilling fluid pressure are suspected of being a frequent cause of lostcirculation. A study of the variables which are believed by the authors to berelated to fracturing led to the premise that the presence of an effective lostcirculation material in a drilling mud stream would serve to plug smallfractures at the moment they are encountered or created and thereby eliminate apossible cause of lost circulation by preventing fluid pressure from wideningand extending the fractures.
A large number of lost circulation materials were classified and tested insimulated fractures and in shallow wells. Granular type materials with agradation of particle sizes were found to be the most effective for plugging.Within the limits of pump ability, the concentration in mud of each lostcirculation material tested was found to be a controlling factor in determiningthe maximum size fracture which could be sealed. A new type centrifugal sorterwas given preliminary tests and found to be capable of concentrating cuttingsfor rejection and reclaiming lost circulation materials.

Introduction
The control and prevention of lost circulation of drilling fluids is aproblem frequently encountered during the drilling of oil and gas wells.
Lost circulation or lost returns may be defined as the loss to formationvoids of the drilling fluids or cement slurries used in the process of rotarydrilling and well completion. The loss may vary from a gradual lowering of mudlevel in the pits to a complete loss of returns. Not to be confused with lostcirculation is the continuous reduction in mud volume caused by the loss of thefluid phase of muds as filtrate and the solid phase as filter cake during thecontinuous filtration process which occurs on permeable formation surfaces.
T.P. 3096
Transient Flow in Gas Transmission Lines
Authors: Olds R.H. , Sage B.H. 
Published: April 2012

Introduction
The transient flow of gases in long pipe lines is a problem of industrialinterest. The present discussion deals with the application of the conservationof momentum and material to the transient flow of gas in conduits which arelong with respect to their diameter. Solutions of the resulting equationsinclude consideration of variations in friction and specific volume of thefluid as functions of time and position along the conduit. The changes in statealong the pipe line are established as a function of time. The methods proposedmay be extended to other situations.
The flow of compressible fluids under steady conditions has been consideredin detail. Primary emphasis was placed on the development of simple means oftaking into account the non-uniform flow realized in long conduits under suchconditions. Binder discussed the essential differences between the flow ofcompressible and noncompressible fluids. Bonilla proposed direct methods ofsolution for equations describing isothermal flow in long pipes. Similarconsiderations limited to steady flow have been discussed by Ruth. Palsgrovesuggested a graphical means of solving specific problems relating to the flowof gases in conduits of uniform section. Some of the basic concepts of the flowof a compressible viscous fluid in straight tubes have been described by Kuo.Problems of this type require knowledge of the equation of state of the fluid.In many cases it has been convenient to assume that the fluid follows therelationship ascribed to a perfect gas.
The treatment of unsteady flow of compressible fluids is less complete. Thisstate of affairs results from the fact that the differential equations relatingpressure and flow rate with time and position for unsteady flow are nonlinearin character. Muskat and Wyckoff presented an excellent treatment of thesituation in laminar flow where inertia forces were not of controllingimportance. Somewhat earlier Hurst discussed the unsteady flow of fluids inpetroleum reservoirs. Hetherington, MacRoberts, and Huntington establishedexperimentally the pressure distribution and accumulative flow rate of naturalgas through an unconsolidated sand. Recently Joffe considered the specificproblem of the flow of natural gas in relatively long pipe lines for unsteadyconditions with emphasis upon the economic feasibility of the storage of gas insuch a reservoir. These discussions were based upon approximations of thepartial differential equations applying to the conditions of flow. The resultswere descriptive of the physical situation and indicated the effectiveness oflarge pipe lines as cyclic storage facilities for natural gas.
T.P. 3081
Relaxation Methods Applied to Oil Field Research
Authors: Dykstra H. , Parsons R.L. 
Published: April 2012

Abstract
A numerical method for solving partial differential equations in steadystate fluid flow is described. This method, known as the "relaxationmethod," has two advantages over analytical methods:practically anyproblem can be solved, anda solution can be obtained quickly.
Adisadvantage is that the solution is not general. The method is applied to coreanalysis and relative permeability measurement to calculate constrictioneffects and to calculate the true pressure drop measured by a center tap in a Hassler type relative permeability apparatus. Further applications aresuggested.

Introduction
Many problems in fluid flow cannot be solved analytically because of thenature of the boundary conditions. For many problems, however, an exact answeris not necessary because boundary conditions are not exactly defined or theparameters describing the porous medium are not accurately known. Therelaxation method can be used to obtain an approximate answer easily andquickly for the flow of incompressible fluids in porous media. The method canalso be used for other types of problems, such as determining the stress in ashaft under load, or the temperature distribution during steady state heatflow. In this discussion only calculations concerned with the flow of fluids inporous media will be considered. The method was introduced by R. V. Southwellin 1935.

Theory
The treatment given here follows that given by Emmons. Consider a porousmedium to be replaced entirely by a net of tubes of equal length and uniformcross-sectional area as shown in part in Fig. 1. Assume that the net of tubesbehaves exactly like the porous medium which it replaces; that is, the net canbe made fine enough to reproduce exactly the porous medium.
T.P. 3145
Laboratory Determination of Relative Permeability
Authors: Richardson J.G. , Kerver J.K. , Hafford J.A. , Osoba J.S. 
Published: April 2012

Abstract
A detailed study of a number of methods of relative permeability measurementhas been made in a search for the technique most suited to routine analysis ofcores taken from reservoir rock. It has been found from tests run on the samesamples of core material by a number of techniques that the Penn State, Hassler, Hafford, and dispersed feed techniques all yield results which arefelt to be reliable. Conditions under which the faster single core dynamictechnique may be used are described. Further work on the calculation ofrelative permeabilities to oil from data obtained by the gas drive method isneeded before this latter rapid method can be utilized.
Correlations between theoretical studies and experimental results have beenobtained in studies of the boundary effect, pressure distribution in two-phaseflow, and gas expansion effects. Previous conclusions that the effects of theoutflow boundary could be made negligibly small have been substantiated.Results of experimentally determined oil and gas pressure distributions along acore sample during flow are presented. Further studies of the effects of rateof flow in the measurement of relative permeability-saturation relations haveshown that results are independent of the rate of flow as long as the flow rateis below the point where inertial effects commence. An analysis of the effectsof a severalfold expansion of gas along the flow path indicates that whilesaturation gradients are induced in the test sample, the errors caused by thisphenomenon in relative permeability measurements are small.

Introduction
Many pages of literature have been devoted to pointing out the need forrelative permeability-saturation relations in reservoir engineering. One of themost attractive ways of obtaining this information is by the analysis ofsamples of core material taken from the formation in question, and againliterature has described many methods for obtaining these data. It is thepurpose of this paper to present the work that has been done in the study ofsome of these published methods together with some other methods that have beenrecently developed in this laboratory. Also, a study of some of the factorsthat influence the laboratory determination of relative permeability-saturationrelations is presented.
T.P. 3375
Sample Grading Method of Estimating Gas Reserves
Authors: Katz D.L. , Turner C.E. , Grimm R.D. , Elenbaas J.R. , Vary J.A. 
Published: April 2012

Abstract
A technique is presented by which well samples and core plugs of dolomiteformations are classified by microscopic examination into seven differentporosity grades. Quantitative values of porosity and permeability aredetermined for each grade by a statistical correlation of the core plug testdata with the porosity grading system. These quantitative values are applieddirectly to the grades exhibited in the well samples for the purpose ofestimating the reservoir void space for wells that were not cored.
The procedure is described for estimating the gas reserves per unit area forthe South Hugoton gas field, but a reserve estimate for the field is notgiven.

Introduction
The miscroscopic examination of well samples and the graphic recording oftheir lithologic qualities and other distinguishing characteristics of variousgeologic formations drilled is both a science and an art of long standing andwide application. Usually the primary objective of a geologist who "sits onthe well" and examines the samples are: to identify the formation beingdrilled, determine the total depth, casing point, and completion interval. Inmost cases the porosity is described, if done at all, in general terms, suchas: trace, scattered, fine, poor, fair, medium, good, excellent, or in someother relative terms. In fields where various geologists have examined samplesand recorded observations on many wells considerable variations in lithologicterms and porosity descriptions occur unless there is primary effort toestablish uniformity of logging observations and standards of recordingobservable porosity.
When an estimate of the pore volume of a reservoir is made a geologicconcept of the processes that control the magnitudes of porosity andpermeability is developed by microscopic examination of well samples. Thecharacteristics and appearances are then mentally related to rather generalquantitative units of porosity based on physical core data from the samereservoir or on such data or experience in other reservoirs that have similarqualities. The reliability of such estimates depends largely on the variationsof the lithology of the formations, the geometric properties of its voidsystem, the extent of comparisons of sample appearances with porosity data, aswell as the uniform recording of all relevant characteristics. This statementis particularly significant for dolomitized limestone formations of substantialthicknesses and heterogeneity such as the Permian Dolomites of the Hugoton gasfield.
T.P. 3374
A Method for Predicting the Tendency of Oil Field Waters To Deposit Calcium Carbonate
Authors: Stiff Henry A. , Davis Lawrence E. 
Published: April 2012

Abstract
The authors previously presented a method for predicting the tendency of oilfield waters to deposit calcium sulfate. The present paper gives a similarmethod for calcium carbonate.
Methods for predicting calcium carbonate scaling tendencies in fresh watershave been available for some time, but these could not be used for brines. Byexperimentally deriving the value of the K term in the Langelier equation, amethod has been developed which applies to waters of high salt content. Astatistical study is included which shows that the experimentally derivedvalues of K are in good agreement with actual conditions. Several applicationsof the final equation to production practice are given.

Introduction
The authors previously presented a method for predicting the formation ofcalcium sulfate scale in oil field waters. Although calcium sulfate depositionis important in production operations, the majority of scale problems involvecalcium carbonate. The present communication discusses a method by which theformation of this type of scale in oil field waters can be predicted.
Calcium carbonate precipitation is caused by a shift toward carbonate in thecarbonate-bicarbonate-carbon dioxide equilibrium. When equilibrium shifts inthe other direction, the precipitate goes back into solution. Since there isusually considerable delay between the establishment of an equilibrium and theprecipitation or solution of calcium carbonate, unstable conditions exist inwhich a water will precipitate or dissolve calcium carbonate on standing.
Tillmans, who did a major part of the early work on carbonate scaling, pointed out that the condition of equilibrium not only indicates the tendencyof a water to scale but also is an indication of its corrosive properties.Previously precipitated calcium carbonate combines with iron to form a densecrust which inhibits corrosion. If the water tends to dissolve carbonate, thescale becomes porous, and electrolytic corrosion takes place. Tillmans work wasextended by several investigators until in 1934 Langelier developed an equationsetting forth the conditions of carbonate equilibrium. By the use of thisequation the pH of a water at equilibrium can be calculated. If the actual pHis higher than the calculated pH, the water has a tendency to form scale. If itis lower, the water has a tendency to be corrosive.
T.P. 3395
The Slip Velocity of Gases Rising Through Liquid Columns
Authors: Stein N. , Elfrink E.B. , Wiener L.D. , Sandberg C.R. 
Published: April 2012

Abstract
This paper presents the results of a study of the slip velocity of gasesrising through liquids in vertical tubes, inclined tubes, and vertical annuli.The data were obtained in gas-liquid systems which included combinations ofair, propane and natural gas (over 97 percent methane) with water, lubricatingoils, and crude oils. The 214 data points obtained in this study along with 11data points reported in the literature are incorporated in an empiricalcorrelation which relates the mean slip velocity of gases flowing throughliquids with the parameters gas rate, tube size, ratio of liquid viscosity toliquid density, gas density, liquid density, and the angle of the tube from thevertical.
The average numerical deviation of the measured slip velocity data fromvalues obtained from the correlation is 9.2 per cent. The average algebraicdeviation between measured and predicted data is 0.31 per cent, an indicationthat the correlation is a satisfactory representation of the data.
The correlation presented in this paper will be useful primarily in thedesign of subsurface gas-oil separation equipment for increasing the efficiencyof oil-well pumping installations, but may perhaps be extended to othersituations of gases rising through liquid columns.

Introduction
The production of oil by pumping is often complicated by the presence offree and dissolved gas in the oil at bottomhole conditions. This gas can bedrawn into the pump barrel and result in "vapor locking" the pump, thusreducing the efficiency of the pumping operation. Large amounts of free gas maybe excluded from the pump by the use of a gas-anchor, which is designed toallow the separation of free gas from the oil before it is drawn into the pump.The design of a suitable gas-anchor depends on a knowledge of the differencebetween the velocity of the free gas and that of the oil as the oil travelsdown toward the pump intake. This rate of gas rise through the oil is termed"slip velocity.
T.P. 3394
A Note on the X-Ray Absorption Method of Determining Fluid Saturation in Cores
Authors: Geffen T.M. , Gladfelter R.E. 
Published: April 2012

Lipson has recently presented a technical note wherein theoreticalconsiderations were used to demonstrate "… that the adsorption vssaturation relation for a linear absorption method is not necessarily a singlevalued function of saturation." It was concluded that the absorption vssaturation relationship is subject to the same hysteretic effect as is the flowbehavior between the drainage and imbibition systems. It is the purpose of thisnote to show, by experimental results, that for the manner in which fluids aredistributed in porous materials during fluid flow, the relative X-rayabsorption vs saturation relationship is single-valued regardless of thesaturation history.
The design of the apparatus used to measure relative X-ray absorption ofcores undergoing fluid flow tests is similar to that described by Morgan, McDowell and Doty. A few modifications have been incorporated in the design toincrease sensitivity and simplicity of measurement. The sensitivity is suchthat for usual types of cores a recording pen movement of approximately 12linear in. is occasioned between the recording of the core dry and when it iscompletely full of an absorbing liquid, a solution of approximately five percent by volume of iodobenzene in a close-cut hydrocarbon fraction, or asolution of 50,000 ppm sodium iodide in water.
Two types of experiments were conducted, one in which the liquid was insidethe core, and the other with the liquid outside the core. Tests with the liquidinside the core were run to cover the saturation range encountered in both thedrainage (gas drive) and imbibition (liquid flood) flow systems. It is pointedout that the same core was used, but the tests were conducted at differenttimes with the recording mechanism balanced at a different position. Therefore, the absolute values of relative X-ray intensity at any saturation are not thesame in each test.
In the second type of test the same core was used, but this time its porespace contained only gas, and various thicknesses of oil contained in plasticcells were placed in front of the dry core.
T.N. 110