bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Quantitative Application of Radioactivity Logs
Authors: Bush Robert E. , Mardock E.S. 
Published: April 2012

Abstract
The object of this paper is to report recent developments in thequantitative interpretation of radioactivity logs. The use of reference linesis described in the application of the new zero radioactivity reference linefor the determination of neutron derived porosities is discussed. Illustratedexamples are shown of logs from the reef limestone of the North Snyder Fieldand from the Lansing-Kansas City limestone of central Kansas.
A method of using an interrelation factor calculated from the neutron andgamma ray curves, called the neutron productivity number, for the estimation ofproductivity from sandstone formations is discussed. When used in a relativemanner the neutron productivity number has aided in predicting whether a givenzone will produce gas or liquid or whether it is too shaly to produce. Examplesof logs from wells in the Freites District, Venezuela, and in East Texas areshown to illustrate the application of the neutron productivity number.

Introduction
The petroleum industry was introduced to some of the preliminary results ofinvestigations into the quantitative interpretation of radioactivity logs inOctober, 1949: It was stated at that time that the methods presented wereentirely relative because they involved the use of reference points obtainedfrom the radioactivity log, i.e., shale reference lines, dense zone referencelines, or a combination of both shale and dense zone reference lines. Theserelative methods offered many advantages to the industry in interpretingradioactivity logs in terms of porosity with particular application tolimestone and dolomite reservoirs. However, these relative methods did notoffer the wide range of applicability desired because the establishment ofreliable reference points from shale in some areas were difficult. It wasrecognized that a more reliable means of establishing reference lines wasvitally needed. Such a method is now available through the introduction of aninstrumental zero device. It is the purpose of this paper to discuss theapplication of this new zero reference to the quantitative interpretation ofradioactivity logs.
Previously all applications of quantitative interpretations of radioactivitylogs have been made in limestone reservoirs with little or no emphasis placedon sandstone reservoirs. A brief resume of investigations into the quantitativeinterpretation of radioactivity logs in sandstone reservoirs is presented here.This discussion deals primarily with the interrelation of the gamma ray andneutron curves and the response of the latter to the density of the fluidsfilling the pore space in relatively homogeneous sandstones of uniformporosity. The authors believe that the methods presented herein are onlyapplicable locally to specific fields and reservoirs, and that they probably donot offer a wide range of applicability.
T.P. 3075
The Southwest Antioch Gibson Sand Unit
Authors: Ockerhauser T.E. 
Published: April 2012

Introduction
The Southwest Antioch Oil Field located in T2&3N - R2&3W, GarvinCounty, Okla., was discovered in February, 1946, by The Globe Oil & Refining Co. and The Vickers Petroleum Co. at their Melinda Gibson No. 1. Oilproduction was encountered at a depth of 6,525 ft in 14 ft of lowerPennsylvanian sandstone.
The producing sand, locally called the "Gibson" or "ThirdDeese," is a sand bar deposit strung along the west flank of the PaulsValley uplift in a northwest-southeast direction. The oil reservoir is definedto the east by the edge of sand deposition along the uplift and to the west bythe gradation of sand into shale. Within the Antioch Unit, the sand dips from150 to 400'Ft per mile southwesterly and has a pay thickness varying from 10 to55 ft and averaging 28 ft.
Several areas of Gibson production have been developed, including the Katiepool on the south, the Elmore Area of the Southwest Antioch Gibson Sand pool, the Southwest Antioch Gibson Sand pool proper, the Southwest Maysville pool andthe New Hope pool on the north. Production extends over a belt 22 miles long byabout two miles wide and is continuous except into the Katie and New Hopepools. It appears that drilling will soon prove these intervening areasproductive. To March 1, 1950, approximately 18,000 acres have been developedwith 450 Gibson wells. It is likely this count will ultimately reach 32,000acres with 800 wells.

Reservoir
The natural production of oil from the Gibson reservoir is primarily due tosolution gas expansion though gravity also plays a part. There is no indicationof water drive or evidence that an initial gas cap existed.
Gibson oil has a stock tank gravity of 43? API and was saturated at theoriginal reservoir pressure of 2,925 psi. It contained 1,340 cu ft of gas perbbl in solution and had a high shrinkage of 70 per cent. Connate water amountsto 15 per cent. Reservoir temperature is 130'F.
Porosity averages 15.5 per cent and permeability ranges from less than onemd to over 1,000. Based on measurement of 400 core plugs from 15 wells, 78 percent of the permeabilities fell within the 10 to 1,000 md bracket and averaged167.
Primary oil recovery is estimated at 140 bbl per acre-ft or 22 million bblfor the present 137-tract unit.
T.P. 3057
The Phase Behavior of a Natural Hydrocarbon System
Authors: Weinaug Charles F. , Bradley Howard B. 
Published: April 2012

Abstract
The phase behavior of a naturally occurring hydrocarbon system whosecritical temperature is near the reservoir temperature has beendescribed.
The same volume per cent liquid was observed for the first time at threedifferent pressures for isotherms immediately below the critical temperature.The shapes of the isothermal equilibrium constant curves necessary to predictthis phenomena are discussed and illustrated.

Introduction
The phase behavior of a number of hydrocarbon systems has been reported;however, very little data are available on natural occurring hydrocarbonsystems whose critical temperature is near the reservoir temperature. Thisappeared to be the case for the fluid studied here; therefore thepressure-volume-temperature data for this system were determined forpresentation.

Method
The PVT data were obtained with equipment similar to that described byWeinaug and Katz, consisting principally of a two-section, double-windowedgauge mounted in a constant temperature air bath. The procedure followed wasessentially that used by Katz and Kurata except that a cathetometer, readingdirect to 0.01 cm, was used to determine the height of each extreme phaselimit.
The system studied was formed by recombining vapor and liquid samples from thefirst stage separator of the well. Portions of these samples were displacedwith mercury into the cell which had previously been filled with mercury. Apredetermined amount of the liquid sample was introduced, while an excess ofvapor was admitted. The resulting mixture was brought to equilibrium at thecondition of the separator during sampling. By adding mercury to maintain thepressure, enough vapor was displaced to give a gas/oil ratio within the cellequal to that produced by the separator at the time of sampling. The remainingmaterial was then considered to be equivalent to the reservoir fluid. Ananalysis of material in the cell, computed from analysis of vapor and liquidsamples and the separator gas/oil ratio, is given in Table I.
T.P. 3097
Primary High Pressure Water Flooding in the Pettit Lime Haynesville Field
Authors: Akins D.W. 
Published: April 2012

Abstract
The case history of a combination gas and water flood instituted early inthe life of a field is described. It was recognized from the beginning thatrecovery would be low, under normal production methods, from the severalseparate, thin beds of porous limestone which had such poor native permeabilitythat the wells would not produce without acidizing. It is thought that thecombination flood gives excellent recovery efficiencies for this type ofreservoir. The chief function of the gas flood now is to maintain bottom holepressure in that part of the reservoir which will not be affected by the waterinjection program until later. Present estimates are that ultimate recoverywill be approximately double the recovery expected under the original solutiongas drive mechanism. Wide (80-acre) spacing has enhanced the economics of theover-all field program by the elimination of more than $5,000,000 worth ofunnecessary wells.

Introduction
The Haynesville Pettit Field was discovered in November, 1941, with thecompletion of T. L. James Co.'s Callie Akin No.1, located in the W ? of the NE? Section 27–23N-8W, Claiborne Parish, La., at an approximate depth of 5,30'Ft. The center of the field is about two miles north and a mile west of thetown of Haynesville, La. A total of 189 producing wells have been drilled on14,500 acres. An additional nine dry holes were drilled. The Louisiana-Arkansasstate line divides the field so that 34 wells are in Arkansas and 155 are inLouisiana.
Governmental sections are divided equally to contain eight production unitsmaking 80-acre spacing where the sections are regular. Along the state line inLouisiana there is an irregular tier of sections, each of which containsapproximately 456 acres. When divided equally into eight production units thespacing is 57 acres per well for these three and a fraction productivesections. All Haynesville Pettit wells are identified by their section numberfollowed by their position in the section as determined by numbering theproduction units counterclockwise beginning in the upper right corner of thesection.
All of the producing wells in the field except two are unitized and operatedby the Haynesville Operators Committee. These two wells are located in theextreme northern part of the field in Arkansas. Efforts to bring them into theUnit are being continued.
The Pettit operators organized the Haynesville Operators Committee and thefield became a unit operation May 1, 1944.
T.P. 3077
Report on the Mamou Field Pressure Maintenance Project
Authors: Crego William O. , Henagan James M. 
Published: April 2012

Abstract
The Mamou Field, located in Evangeline Parish, La., is an elongatedanticlinal structure on the downthrown side of a major east-west fault with oiland gas production from the upper part of the Wilcox formation. Two mainproducing horizons occur at an approximate depth of 11,500'Ft and have beendesignated the Morein sand and the Deshotels sand.
The upper sand (Morein) had an original bottom-hole pressure of 6,788 psig, which is some 1,500 psi above the normal pressure for that depth. Oilproduction with high gas/oil ratios and fluid analyses giving high shrinkagefactors prompted a study of the reservoir in its early stages. The resultsindicated a closed reservoir producing under solution gas drive with lowexpected ultimate oil recovery.
The early study of the Wilcox formation and its contained hydrocarbonsresulted in the presentation of the data to the Department of Conservation ofthe State of Louisiana, with suggestions for field rules and a request forpermission to inject extraneous water into the Morein sand. The water injectionplans eventually led to complete unitization of working and royalty interests, to the construction of a gasoline plant, and to a central tank batteryinstallation for the field. Deshotels sand wells were reworked to the Moreinsand, and the water injection system was installed and ready for continuousoperation in the early part of 1949. The injection of water was started in timeto arrest the bottom-hole pressure decline at or near the bubble-pointpressure. This injection was calculated to increase the ultimate recovery andto conserve natural resources. Pressure maintenance, the extraction of LPGproducts, and the sale of residue gas (early 1950) represent an attempt toproduce an oil field with utmost efficiency.

Introduction
The two principal Wilcox oil horizons in the Mamou Field are the Morein sandand the Deshotels sand, occurring at 11,500'Ft and 11,700'Ft subsea, respectively. Minor oil production has been encountered in Morein stringersands. (Fig. 1.)
This paper deals only with the Morein sand, which is blanket over the MamouField. It is, however, segmented by the northwest-southeast "E" faultas shown in Fig. 2. The west segment is the area involved in the waterinjection pressure maintenance program. To date the east segment has operatedlargely under the influence of a strong water drive.
The paper presentsbrief history of field development,resume ofreservoir conditions which led to the decision to inject extraneous salt waterinto the principal producing horizon, andsummary of reservoir analysisand performance.
T.P. 3192
Interstitial Water Determination by an Evaporation Method
Authors: Messer E.S. 
Published: April 2012

Abstract
A knowledge of the magnitude of the irreducible interstitial water in aporous medium is so important to petroleum engineering that its determinationhas become routine in core analyses.
The method of determination, being a production problem, should encompassthe basic requirements of simplicity in technique and calculations, withreproducible results obtainable in a short interval of time. The results of theevaluation tests outlined in this report indicate that the evaporation methodfor determining the irreducible water is a technique which meets therequirements.
The procedure consists, as the name implies, of permitting the saturant inthe pore spaces to evaporate until only an irreducible volume remains. Thedetermination of this volume can be made either graphically or by amathematical comparison of fluid flows; the time required for eachdetermination being dependent on the fluid used.
When fluids other than those having reservoir characteristics were used, avolume factor had to be calculated which was based on the relative volume ofvarious liquids adsorbed on grain surfaces and retained in pores. This factormade possible the calculation of an irreducible water volume when more volatilefluids such as toluene and benzene were used as the saturants.
Also presented is the theoretical discussion necessary for the calculationof the capillary pressure as determined from the evaporation curve. Acomparison is made between the calculated values and those obtained byexperimental means.

Introduction
In all geological formations there exists, in the pore spaces of the rockstructure, water that is held in a state of equilibrium between capillary andhydrostatic forces. "Interstitial water" is the term given to thiswater and is defined as that water coexisting in the pore space with the oilprior to exploitation. The term "connate water" has often been usedsynonymously with this term; however, this can be true only by a specificdefinition since, geologically, it means the water in place at the time therock structure was formed.
The quantity of the interstitial water is a variable factor in anyformation, since it depends on the hydrostatic forces present in anymultiple-phase system. These forces may become unbalanced by the introductionof an extraneous force such as the raising or lowering of the "watertable" or the migration of oil into a water-filled formation. Anyunbalanced force results in a change in the interstitial water.
There exists, however, an irreducible interstitial water, for a particularsand, that is the fraction of the pore space occupied by water when thecapillary pressure at the particular point in question is at an equilibriumwith the hydrostatic head of the oil sand in the reservoir. For this discussionthe term "irreducible water saturation" will be used in place of"irreducible interstitial water saturation" for the sake of brevity;however, they are understood to be identical.
T.P. 3076
The Laterolog: A New Resistivity Logging Method With Electrodes Using An Automatic Focusing System
Authors: Doll H.G. 
Published: April 2012

Abstract
A new electrical logging method called Laterolog is described which providesfor better recording of formation resistivity. In this method a current, preferably of constant intensity, is forced into the formation perpendicularlyto the wall of the hole as a sheet of predetermined thickness by means of aspecial electrode arrangement and of an automatic control system.
The essential advantages of the Laterolog over the regular resistivity logsare explained. With the Laterolog, the mud column has much less influence thanwith conventional methods. The Laterolog is, therefore, particularly useful inwells drilled with highly conductive mud. Moreover, when the electrode systemis located opposite a bed of moderate or small thickness, the disturbing effectof the adjacent formations becomes practically eliminated, provided the bed isthicker than the sheet of current, which itself is usually a few inches to afew feet thick. The sequences of beds are, therefore, much more sharplydifferentiated, and, in many cases, it is possible to read directly from thelogs values close to the true resistivities of the formations without furthercorrections.
Field examples are shown to illustrate the results of the method in varioustypes of formations.

Introduction
As soon as it was introduced into the petroleum industry, electrical loggingproved to be a powerful instrument for the delineation of the strata traversedby bore holes and for correlation of such strata. Research and engineeringefforts were mostly devoted at this early time to the design of the techniqueswhich could provide the best data for these purposes.
Later, attention was directed toward the quantitative analysis of electricallogs, in order to obtain information on reservoir characteristics, and inparticular on oil and water saturation. Efforts have been made, accordingly, with a view to improving the already existing methods, or to finding newmethods which could satisfy these new requirements.
Quantitative analysis implies a determination as accurate as possible of thetrue resistivity of the formations. In fact, however, the "apparentresistivity" recorded in front of a given bed by a conventional electricallogging method is frequently quite different from the true resistivity of thisbed. This is due to the combined influence of the mud column, of the adjacentformations both above and below the bed, and of the invaded zone, in which theoriginal fluid has been more or less replaced by mud filtrate.
T.P. 3198
Fluid Distributions Characterizing Gas-Liquid Flow
Authors: Rose Walter 
Published: April 2012

It is the purpose of this note to call attention to the circumstancecomplicating the attainment of uniform gas-liquid distributions in multi-phaseflow systems, and especially in those of the so-called Hassler type. Althoughthe complication arises directly as a consequence of gas compressibility andthe dependence of fluid distributions on interfacial curvature phenomena, little reference to the problem has yet appeared in the literature. In fact, itis only the paper of Geffen et al. which gives any experimental evidence that aproblem exists. On the other hand, previous authors have made the tacit, albeitfallaceous assumption that uniform gas-liquid distributions automatically areestablished in linear flow systems by the expedient of maintaining the pressuregradients equal in the flowing gas and liquid phases. Such a device, it can beshown, will succeed only if the immiscible fluids are both equally compressibleor both essentially non-compressible. Another necessary condition requiredbefore uniform fluid-fluid distributions can be achieved is that the porousmatrix is isotropic.
Uniform fluid saturation distribution conditions obtain in isotropic mediaonly when the curvature of each interface of contact between wetting andnon-wetting fluids is everywhere the same throughout the interspaces. This is anecessary condition which follows from the consideration that variation ininterfacial curvature gives rise to finite capillary pressure gradients andtherefore to variation in the saturation distribution. That this is not asufficient condition follows from the consideration that hysteric possibilitiesallow for different saturations even though the capillary pressure gradient iszero. In any event, it will be recalled that it is the intent in the Hasslerscheme of relative permeability determination to obtain initially (by thecapillary pressure drainage or imbibition process) uniform conditions of fluiddistribution in the core sample, and then to maintain this uniformity duringmixture flow so that the resultant fluid mobilities which are calculated willrefer to steady-state transfer under fixed conditions of uniformsaturation.
T.N. 66
The Interpretation of Chemical Water Analysis by Means of Patterns
Authors: Stiff Henry A. 
Published: April 2012

Abstract
The classification and correlation of water analysis data presents manyproblems which can be solved by graphic methods. The pattern system, a new typeof graphic procedure described in this communication, is believed to haveseveral advantages over older methods. Examples of the application of thepattern system to the solution of problems encountered in petroleum productionare given.

Introduction
Several graphic methods for presenting analytical water data have beendeveloped and are now in use. It is believed, however, that a recentlydeveloped type of graph called the "pattern" offers several advantagesover other methods. This system presents a better picture of the total saltconcentration than is usual in such graphs. The effect of dilution orconcentration has been reduced to a minimum, and at the same time distinctionbetween various types of water has been improved. The system is extremelyversatile, yet so simple it can be plotted on ordinary graph paper and adaptedto almost any type of filing system.

Discussion
The essential feature of the pattern system is the graph shown in Fig. 1.Horizontal lines extending right and left from a vertical line at zero form thegraph. Positive ions are plotted to the left while negative ions are plotted tothe right. The figure immediately beneath each ion gives the scale. Most oilfield waters can be plotted on a scale where 100 milliequivalents of sodium andchloride and 10 milliequivalents of each of the other ions are represented byone scale unit.
T.N. 84