bluuebunny/crossref_metadata_2025_split huggingface dataset:
Evaluation of Pressure Maintenance by Internal Gas Injection in Volumetrically Controlled Reservoirs
Authors: Patton E. Charles 
Published: June 2014

Abstract
A comprehensive discussion is presented of a proposed method for utilizing thedeterminable basic physical facts about tight, volumetric-type reservoirs andtheir contained fluids, to arrive at the feasibility of injecting gas thereinand to estimate the minimum about the profit to be derived there from. A methodis introduced for correlating laboratory relative permeability data with fieldperformance history, and a method of relating the one to the other so as toenable predictions to be made of future performance based on past performance.This incorporates the substitution into the material-balance equations of afactor designed partially to take into account deviations from ideal behaviorresulting from nonhomogeneity of the reservoir rock, the importance of thisfactor to the reliability of such predictions is not to be minimized.
A theoretical interpretation of the most dearly correct method of applyingflash and differential laboratory data in their appropriate places in thematerial-balance equations, and a set of symbols to accommodate the distinctionbetween these two different types of data is developed.
A set of equations for converting material-balance predictions directly to atime basis is given; a method of predicting the time at which the fieldeconomic limit will be reached, and a tentative method for predicting relativenumber of wells on the pump at any time under pressure maintenance as comparedwith primary performance have been described. These three concepts areprerequisites for the accurate evaluation of the economic benefits of pressuremaintenance.
The equations and methods described may also be utilized to predict therelationship between gas-production rate and time to serve as a basis fordesign of proper size gasoline or compressor plant to accommodate an entire oilfield, or to predict the most economically advantageous time to begin agas-injection project.
The sale of residue gas in connection with the operation of a reservoir bynatural depletion under some circumstances may prove economically superior topressure maintenance y gas injection in spite of the expected increases inultimate oil recovery by the latter type of operation. A situation such as thismay arise from the interrelationship of the many physical and economicvariables involved.
T.P. 2098
Volumetric Behavior of Oil and Gas from Several San Joaquin Valley Fields
Authors: Sage B.H. , Olds R.H. 
Published: June 2014

Abstract
The formation volume and volume of the liquid phase of oil and gas obtainedfrom four fields in the San Joaquin Valley have been investigated at pressures, temperature, and gas-oil ratios comparable to those encountered in underground?reservoirs. All the fields covered in this investigation yielded a product of agas-oil ratio in excess of 5000 cu ft per barrel and the gravity of the tankoil for the four fields in question varied between 52' and 63' API. The resultsof the investigation, together with analytical data concerning the compositionof the oil and gas, are submitted in tabular form. Rough correlations of theformation volume as a function of pressure, temperature, and gas-oil ratio andof the retrograde dew-point pressure as a function of gas-oil ratio, temperature, and gravity of tank oil are presented. It was not found feasibleto correlate simply the formation volume of the liquid phase as a function ofthe applicable variable. It is desired to emphasize that these correlations areconsidered applicable only to the range of conditions covered in thisinvestigation and for systems of similar nature and composition.

Introduction
Information concerning the physical properties of mixtures of oil and gas fromparticular fields have often been employed in predicting the situationsobtaining in underground reservoirs. One of the earlier studies of this naturewas the work of Beecher and Parkhurst, while a more recent study of theDominguez Field presented detailed volumetric data in the two-phase as well asin the single-phase regions. Although these studies were confined to individualfields, their results proved of value in application to other fields. It hasrecently been shown 3,4 that it is possible in the region of low gas-oilratios' to correlate the? volumetric behavior of naturally occurringhydrocarbon mixtures from a single geographical area with sufficient accuracyto be of industrial value. For this reason it is considered of interest tosubmit information concerning the volumetric behavior of oil and gas mixturesfrom four different fields in the San Joaquin Valley and, in combination withsimilar published data concerning mixtures of oil and gas from the Paloma fieldin the same area, to show rough correlations between the composition and thebehavior of materials from these fields.
T.P. 2153
A New Well-completion Technique
Authors: West Thomas S. 
Published: June 2014

Abstract
Completion and production data presented for three wells in the Oakville areaof Live Oak County, Texas, which were completed near the gas-oil or water-oilcontact, indicate that coning may not be as prevalent a cause of failure insuch cases as is commonly assumed. Failure in the cases discussed is indicatedto be due instead to:erosion of the formation,flowing out of mudfilter cake, orfailure of the cement.
An open-hole gravel-pack type ofcompletion procedure is proposed for preventing failures of this kind bypreventing movement of all solid material in the space in which completion ismade. Various combinations of layers of gravel, sand, and cement are utilizedfor this purpose.
Experimental results and theoretical discussion as to the applicability ofgravel pack completion are included.

Introduction
This paper is primarily a study of the reasons for failure of oil-wellcompletions near the gas-oil or oil-water contact, and suggests a procedure forincreasing the efficiency of this type of completion.
The value of improvement in completion effectiveness near the gas or water zoneis not confined, however, to wells of relatively thin oil columns. Thick oilcolumns become thin as depletion progresses. It would seem to follow that theminimum distance from the gas or water zone at which completion can be made ina new well indicates the limit to which depletion may be carried in a wellhaving an oil column of any initial magnitude.
Only four ways can be postulated in which high gas-oil or water-oil ratio caninitially occur if the zone exposed for production is within the oilcolumn:Failure of the cementing material.Vertical coning.Failure along the boundary between the cement and the wall of thewell.Failure of the formation comprising the wall of the well.
Cementing materials such as portland cement and plastics have reached a highstage of development. Failures of this type are probably due almost always toextraneous causes such as mud contamination rather than to faulty cementingmaterial.
Vertical coning can and obviously does occur. However, the usual occurrence ofthin impermeable streaks in sand sections and the success with which open-holedrill-stem tests can be made near the gas-oil contact suggest that over-alleffective vertical permeability, and in turn vertical coning, is less prevalentthan frequently is assumed.
Much has been written on failure by flowing out of the mud filter cake betweencementing material and the formation. A filter cake is always present if, priorto cementing, mud has come in contact with a permeable formation at pressuresexceeding the pressure head of the fluid it contains.
T.P. 2094
Potentiometric-model Studies of Fluid Flow in Petroleum Reservoirs
Authors: Lee B.D. 
Published: June 2014

Abstract
A simplification of the method of Hurst and McCarty for conductingpotentiometric model studies by the single probe method is presented along withexperimentally determined invasion patterns for certain idealized flowproblems. The analytical solution for one class of these problems is given.Finally, a general description is given of a newly developed instrument whichpermits direct mapping of flow lines and determination of transit times inpotentiometric-model studies.

Introduction
The object of this paper is to present:A simplification of the method of Hurst and McCarty for conductingpotentiometric-model studies of oil and gas reservoirs by the single probemethod.Results of a series of studies of certain idealized flow problems and thegeneral conclusions to be drawn therefrom.A description of a dew instrument, the Chronocartograph, which greatlyreduces the labor and time required for conducting potentiometric-modelstudies. Certain general conclusions may be drawn as results of theinvestigation of the idealized flow problems.
They are:Injection and extraction areas should be separated by as great a distance asconditions permit since, in general the recovery prior to first breakthroughtends to vary as the square of this distance.Little advantage is to be gained by use of more than eight injection wellsor groups of injection wells for the case of circular productive limits.Elongated shapes if productive limits are best exploited by injection on theextended major axis only, with a line of extraction wells lying on the majoraxis.The use of peripheral injection wells for elongated shapes is permissible, if necessary, but requires extension of the lines of extraction wells.
The exploitation of an oil or gas field is effected either by the expansion ofthe gas and oil, or by their displacement by another fluid. Both methods may beused simultaneously. When the displacement of the oil or gas is the controllingfactor there arises the problem of mapping the progress of the boundary betweenthe fluid in place and the displacing fluid. This problem is of particularinterest in the operation of a cycling project in a gas-condensate field, wherethe wet gas is produced from one or more wells, commonly called ?extractionwells?. This wet gas is taken into a processing plant where the condensate isremoved. The remaining "dry" gas is injected back into the field through one ormore wells, the gas for future use and also to maintain the pressure in thefield.
T.P. 2262
Some Theoretical Aspects of Well Drainage and Economic Ultimate Recovery
Authors: Moyer Vaughn 
Published: June 2014

Abstract
A method for incorporating well drawdown effect into reservoir calculations ispresented in detail, together with examples of its use for widely divergentconditions that could be normally encountered in oil reservoir sands. Tentativeconclusions as to the effect such factors as permeability, producing interval, well spacing, or well damage caused by completion or repair practice could haveupon economic ultimate recovery are reached. It is carefully pointed out thatthe conclusions reached are subject to limitations indicated in the text, andplaced upon all calculations made in the paper.

Introduction
Papers have been presented I-a in which theoretical depletion histories forreservoirs under equilibrium conditions and no appreciable well-bore drawdownpressure are determined. However, except for a limited number of cases, appreciable drawdown pressures in a well bore exist, and pressure andsaturation gradients consequently vary throughout a reservoir.
This paper is an attempt to incorporate well-pressure drawdown into reservoirhistory, and to analyze certain factors, such as those involving recovery, wellspacing, and productivity index, from the standpoint of permeability anddrainage radius. By incorporation? of drawdown into reservoir history, it isbelieved that theoretical considerations will more closely approximate actualreservoir behavior experienced in an oil field. For purposes of simplification, a solution gas-drive typefield, without primary gas cap, has been selected.

Basic Data and Assumptions
Details of equilibrium saturation conditions for no drawdown production forvarious pressures in a reservoir are determinable by methods described byseveral authors permitting the construction of a curve of oil saturation vs.pressure for any selected combination of initial interstitial water andhydrocarbon saturation (Fig I). This curve is then a description of equilibriumsaturation conditions at any given pressure in a reservoir.
Developing the above, details of saturation and flow permeability may thus bedetermined for any increment or portion of a well drainage area or reservoir, In this manner the effect of pressure differential (draw down) may beincorporated into reservoir and well drainage considerations.
It is pointed out that this method thus makes use of no-drawdown equilibriumproduction data, superimposing a drawdown effect upon them. It also assumesthat net flow conditions in any considered increment of reservoir are notmaterially altered by the entrance of fluids from other increments into them, but approach equilibrium for the existing pressure and saturation (i.e., eachincrement behaves in more or less independent fashion, dependent largely uponthe equilibrium considerations mentioned above).
T.P. 2201
Radioactive Markers in Oil-field Practice
Authors: Doll H.G. , Schwede H.F. 
Published: June 2014

Abstract
This paper describes a method to provide identification of particular depths ina borehole through the use of radioactive markers. The correlation of a marker, placed in the wall of a borehole, with known points of the electrical log andwith the casing collars in the cased hole permits accurate positioning of toolswith respect to a formation, regardless of absolute depth. Such a process isparticularly useful in gun perforation of a casing in a well. Technique andequipment are discussed and illustrated. Examples are given of practicalapplication in the field.

Introduction
During the past decade the search for petroleum has increased the importance oftesting zones at depths in wells which have become progressively deeper. Thedevelopment of new techniques, such as electrical logging, has permitted theidentification of producing formations which consist of comparatively thinstrata. When thin beds are to be produced at great depths, the problem ofpositioning tools accurately to place the well in production becomesacute.
Continuous consideration is being given in the petroleum industry towards theimprovement of depth measurements in a borehole. The accuracy in absolute depthmeasurements, whether made in an open or cased hole, whether determined by a cable or a drill pipe, depends upon a number of factors, such as tension, temperature, and calibration.
For example, the effects of tension from the weight of 10,000'Ft of drill pipeand the thermal expansion of this length of pipe, where its average temperaturehas increased 50'F, will produce an elongation as much as 8 ft. The effects ofsuch factors can be minimized through the use of care in depth measurements, the application of corrections based on experience, and continuous calibrationor checking.
The fact that different methods and different tools are used to determine thedepths of formations in wells will sometimes give rise to a difference betweenmeasurements. It is evident that an important requirement in a well is theability to locate at will any subsurface point. While absolute depthmeasurements have improved in recent years, it is reassuring to have othermeans to verify, for example, that a casing is perforated at a particular placewith reference to a zone within a formation. Such a check on measurements maybe had by placing a reference marker at a point known with respect to theelectrical log of the borehole. That point is usually chosen to be in proximityto the zone to be perforated. Thus, only short relative depth measurements aremade and any inaccuracy becomes very small and of minor importance.
T.P. 2261
Preventing Corrosion in Gas-condensate Wells
Authors: Menaul P.L. , Spafford P.P. 
Published: June 2014

Abstract
This paper discusses the most dangerous form of corrosion encountered incondensate well oil production, the discovery of the agent causing thiscorrosion and the remedial chemical treatment proved effective by field use.The injection of ammonium hydroxide, even as little as one quart per day, hasproved effective in preventing gas-condensate well corrosion. The injection of"Bone oil" is applied to wells producing brines containing calcium andmagnesium salts.

Introduction
The severe corrosion of equipment in high pressure gas condensate wells hasbeen a problem for several years and numerous papers have been presented on thesubject.
The term ?gas condensate? or ?distillate well? is applied to a distinctvarieties of hydrocarbon producing well, the characteristics of these wellsbeing high bottom-hole (formation) pressures and temperatures and high gasproduction. These wells usually produce about 40 gal of water per million cubicfeet of gas and the gas contains from 0.1 pct to 2 pct carbon dioxide. In theoperation of this type of well, the operators soon noted severe internalcorrosion of the pipe carrying the production. In some instances the welltubing has been found to be corroded to perforation in eight months. The highwell head pressure of 2500 to 8000 psi makes any weakening of the wellequipment by corrosion extremely hazardous. Bursting of the wells equipmentresults in very expensive repair operations and may result in the loss of thecostly well, or even loss of life.
In November 1944, a gas-condensate well in a Gulf Coast field producing from9500'Ft showed a tubing leak. The well was ?killed? by filling it with mudthrough the tubing, and then the tubing was pulled. Corrosion was found to havecaused several perforations in the tubing, Fig. 1. While the mud was beingcirculated to kill the well, a high pressure jet from the corroded hole in thetubing perforated the casing and damaged the well to the extent that the costof repairs amounted to $75,000.
In November 1944, another gas-condensate well in a Gulf Coast field producingfrom 11,400'Ft. showed tubing failure. This well had been producing an averageof 2,500,000 cu ft of gas daily for two years. In the workover of this well, itwas found that a hole one inch in diameter had corroded though the tubing andthat corrosion had reduced the wall of the tubing to less than half thestandard thickness over large areas of the interior of the tubing. It was foundthat corrosion had also caused two leaks in the casing. After four months spentin an attempted workover failed to make the well safe for further production, the well was plugged and abandoned at a total low or $300,000.00.
T.P. 2229
Well Flowmeter for Logging Producing Ability of Gas Sands
Authors: Vincent R.P. , Leibrock R.M. , Ziemer C.W. 
Published: June 2014

Abstract
The Stanolind flowmeter, which employs a hot-wire anemometer connected in aWheatstone bridge circuit, has proved useful for determining the relativeproductive ability of individual sand members of gas wells. The operation ofthis instrument in measuring gas velocities in the well bore above eachproducing member has provided both a direct and accurate means of analyzingreservoir performance.
Results of tests conducted with the well flowmeter in the Hugoton gas field ofwestern Kansas have indicated some rather unusual production characteristics.In two cases it was found that all or the greater part of the total gasproduced was coming from one section in wells where four "pay" sectionshad been perforated individually. These actual measurements contradict in manyinstances the indications of data obtained from electric logs and from coreanalysis; the fact that these latter sources often give incorrect results, demonstrates the necessity of a method, such as is provided by the wellflowmeter, for accurately determining the amount of gas coming from eachproducing member.

Introduction
In any gas well where a number of pay sections have been perforatedindividually and are producing to a common outlet, the question arises as tothe relative amounts of gas being passed through each set of perforations. Inthe past it has been the policy to depend on core analysis to estimate relativeproductivities, or, where the sections were not cored, to obtain some idea ofproduction characteristics from electric log studies. The weaknesses in thesemethods are readily apparent and indicate the need for more reliable means ofmeasuring gas flow from each zone. The Stanolind flowmeter was developed forthis purpose.
Preliminary tests were made with the instrument in the Katy gas field nearHouston; however, the bulk of the routine work with the well flowmeter has beenconfined to the Hugoton gas field in western Kansas, where results obtainedhave been encouraging.
A description of the instrument, the field technique employed in testing, and afew of the results obtained in the Hugoton area are discussed in thispaper.

Description of Instrument
The well flowmeter is 1 ? in. od and 7 ft long; it is entirely self-contained, can be run through tubing as small as 2 in. id in wells with high pressure(4500 psi) and temperature (210'F) and is lowered on a wire line commonly usedfor other instruments of the bottom-hole type at falling rates up to 500'Ft perminute. It will detect gas flow as low as 10'Ft per minute linear velocity, andyet withstand and record velocities of 1000'Ft per minute without damage to thedetecting element. Killing the well is not required nor desirable for running aproduction profile when using the instrument and it is necessary to stop flowfor only a short time.
T.P. 2263