bluuebunny/crossref_metadata_2025_split huggingface dataset:
Viscosity Characteristics of Clays in Connection with Drilling Muds
Authors: Broughton G. , Hand R.S. 
Published: June 2014

For the past few years a great amount of work has been done on the viscositycharacteristics and gelation of clay suspensions, much of which has beenreported in papers published by the Institute. Important reviews have been madeelsewhere by Evans and Reid, Marshall and Clews, Macey and Rigby, the last twoon the general properties of clay. It is unnecessary, therefore, torecapitulate past work beyond recalling that three explanations for the highviscosity and gelation of clay suspensions have been put forward. For lack ofmore exact nomenclature, these may be called the water hull, mechanicalinterference and attraction-repulsion theories. The first pictures the clayparticles as surrounded by relatively rigid water envelopes, which increaseeffective volume; the second emphasizes the mechanical interference of platyparticles or their agglomerates; while in the third the particles are assumedto be held relatively rigidly at a distance from each other determined by thebalance between the attractive (van der Waal's) forces and the electricalrepulsions of the charges. This article presents fresh data on claysuspensions, particularly on the influence of previous flow history of thesuspensions, specific contra-ions, temperature, solvation and particle size, inan attempt to contribute to the solution of the problem.

Experimental Procedure
Preparation of Samples.-Suspensions of the raw clays were prepared by addingthe clay to water with vigorous stirring and allowing the mixture to stand forseveral hours. In bentonite suspensions, the sand that settled was removed.Many of the suspensions were put through a homogenizer for deflocculationbefore use. The suspensions containing alcohol and pyridine were prepared bygradually adding a known quantity of the C.P. reagent to the clay, shakingafter each addition. They were then allowed to stand for two days beforemeasurements were taken. All concentrations are expressed on a weight per centbasis.
T.P. 1002
Relation of Gas-well Spacing to Ultimate Recovery
Authors: MacRoberts D.T. 
Published: June 2014

This paper embodies the results of theoretical studies concerning gasreservoirs, especially the effect of drilling programs of various intensitiesupon pressure depletion and ultimate recoveries. The primary objective has beento determine the net quantity of recoverable gas that could be obtained as aresult of each additional well, in comparison with the gas that might besecured from a single well ideally placed with respect to both acreage andgeological structure. No method is yet known whereby the relative merits ofintensive and sparse drilling can be compared experimentally; a reservoir musteither be drilled closely or developed with wide spacing, but both programscannot be conducted simultaneously. Hence, the analytical method seems to bethe only approach to the problem.
While the present state of our theoretical knowledge does not offer a precisesolution to the problem of gas flow in sand bodies, it takes such appropriatecognizance of the limitations of the methods used as to restrict any answerobtained to the realm of engineering accuracy. In solving the problem for theaverage gas field, it was found that practically the same answers resulted asto pressure distribution, regardless of the size of the drainage radius, eventhough the latter was assumed to vary from a few feet as a minimum to that ofthe entire reservoir as a maximum. Such limits represent extreme possibilities;therefore, the practical conditions that are associated with normal developmentprograms, in which wells are placed in the center of tracts varying in sizefrom 40 to 640 acres, will of necessity result in less extreme variations thanthose indicated in the tables accompanying this paper. Stated more concisely, the amount of gas unrecovered at abandonment (of the particular field used forillustrative purposes) will lie somewhere between 4.6 and 6 per cent of thetotal original content, no matter how intensively the field is drilled.
Gas reservoirs may be divided into two general types, those in which the energyis intrinsic, and those of which the energy is extrinsic.
T.P. 868
Application of Vaporization Equilibrium Constants to Production Engineering Problems
Authors: Katz Donald L. 
Published: June 2014

The equilibrium constants developed by Souders, Selheimer and Brown havebeen very useful tools in predicting vapor-liquid equilibria during the pastfive years. Their equilibrium constants were computed by assuming idealsolutions and recognizing the deviations of vapors from ideal gas laws. Thesame fundamental concepts were used by Lewis and co-workers for predictingvaporization phenomena by means of fugacities.
The equilibrium constants are a function of temperature and pressure andmight be considered as replacing the ratio of the vapor pressure to the totalpressure of Raoult's law. They may be used to compute the vapor or saturationpressure of a liquid or the dew point of a vapor for any pressure ortemperature from the analysis of the mixture much as Raoult's law is used.Likewise, the quantity of a mixture that will vaporize at any equilibrium.temperature and pressure and the composition of the vapor and liquid may becalculated.
The purpose of this paper is to review the available equilibrium data ofinterest in petroleum production, to discuss the auxiliary physical propertiesof the hydrocarbons, and to present typical uses of the equilibrium constants.The particular applications chosen are the computation of the results of stageseparation of crude oil and natural gas, the calculation of a pressure-volumecurve of a crude oil-natural gas mixture, and information gleaned from aconsideration of reservoir equilibria.
A Design for More Effective Proration
Authors: Pogue Joseph E. 
Published: June 2014

Over a period of years the writer has presented a number of studies onvarious aspects of proration, in a progressive attempt to analyze criticallyand constructively the economic complexities of this interesting institution, which in a decade has revolutionized the economics of oil production in theUnited States. In the course of the investigations leading to these papers, thechanging nature of proration and the principles underlying its evolution havegradually become clear, so that it is now possible to depart from theanalytical method and to construct a synthesis of the steps that, if furtheredby the industry, should carry proration past the economic hazards that stillsurround it to the goal of maximizing the value of the petroleum resource tothe industry and the public alike.

Nature of Proration
Proration literally means the allocation of demand among competing producerson a pro rata basis, but the term now carries a much broader significance forit is employed to describe the entire process by which the production of crudeoil in the United States is regulated. There is naturally much confusion ofthought on the subject, for proration is an evolving system of control basedupon principles of conservation and equity and embracing a body of practicesthat are tending to adjust themselves to the needs of the situation but aresubjected to varying and divergent influences in the process. As it is nowconstituted, proration is a planned production measure designed to preventwaste, insure ratable takings, and balance supply and demand.
T.P. 1028
Development of the Turner Valley Gas and Oil Field
Authors: Taylor Vernon 
Published: June 2014

Canada's oil production is obtained almost entirely from the Turner Valleygas and oil field, in the Province of Alberta. This field, about 30 milessouthwest of the city of Calgary and approximately 115 miles north of theUnited States border, supplied 92 per cent of production in Canada during 1937. In 1938 considerable development took place in this field and total productionfor the year amounted to 6,688,716 bbl., an increase of 3,922,146 bbl. over theproduction in 1937, which increased the percentage of production toapproximately 97 per cent of Canada's total. In the British Empire, Canada'sproduction is thus comparable to that of Bahrein Island and Burma, each ofwhich produced approximately 7,800,000 bbl. in 1937, being second to Trinidad'sproduction of 15,500,000 bbl. The total production of the British Empire inthat year amounted to 2.07 per cent of the world's total.

History
Development of the Turner Valley field commenced in 1913, when a well wasstarted near a gas seepage on the banks of the South Fork of Sheep River in thecentral part of the Valley. This well found small quantities of a light crudeoil in beds of Upper Cretaceous age and precipitated a wild boom in 1913–1914 which ended with the beginning of the Great War in 1914. A small amount ofdrilling was done in the years from 1914 to 1922 and a few wells found smallcrude-oil production in the upper sands.
In 1922 a few wells were started, including the Royalite Oil Company's No. 4 well (R, Fig. l), which became the discovery well of naphtha production fromthe Paleozoic limestone. In October 1924, this well was completed at a depth of3740 ft., being approximately 300 ft. in the limestone, with an initial flow of600 bbl. of 72? A.P.I. gravity naphtha and 20,000 M cu. ft. of gas per day.Intense activity was not started until the latter part of 1928, when the OkaltaNo. 1 well (Q, Fig. 1) was drilled, with an initial production of 500 bbl. ofnaphtha per day. This well was only 1? miles from Royalite No. 4, but it wasapproximately 1300 ft. lower on structure and potentialities of the field wereconsiderably increased.
T.P. 1099
Effect of Pressure Reduction upon Core Saturation
Authors: Botset H.G. , Muskat M. 
Published: June 2014

Any information that will increase the accuracy of our knowledge of theconditions prevailing in petroleum reservoirs should be of direct value in thedetermination of the proper operating technique as well as in the estimation ofreserves and of ultimate production. The obvious method of obtaining thisinformation is by studying a sample of the reservoir rock and its contents. Inany such study, the problem of primary importance and maximum difficulty isthat of getting the core to the surface in such a manner that its originalfluid content is undisturbed, which has so far proved to be an impossible task.Though it might be rash to say this will never be done, it is certainly safe toassume that a method for the recovery of a core at the surface in itsundisturbed original state may not be developed in the immediate future, andcertainly will not be forthcoming without a great deal of costlyexperimentation.
Therefore any information that may be obtained that will help to correlate thestate of a core (its fluid saturation) at the surface with its condition at thetime it was drilled should be of value to the petroleum industry. Theexperiments described in this paper were undertaken with the purpose ofdetermining, if possible, any relationship that might exist between thesaturation of a core at the surface and its original fluid content. Noconsideration has been given to the question of contamination by penetration ofdrilling water, since this problem has been extensively studied by otherinvestigators. Furthermore, it was regarded as outside the scope of theseexperiments, which were concerned only with the effect of pressure reductionupon the liquid content of cores.
In an experimental study of this sort involving a large number of variables, accurate control of all factors is very important. The essential and obviousprocedure is to vary systematically one factor or condition while keeping allthe others constant, which necessarily involves a rather protracted andsometimes tedious experimental program.
T.P. 1025
Multistage Stabilization of Crude
Authors: Gibson H.S. 
Published: June 2014

A process that has come to be known locally as ?multistagestabilization" has been developed in the Haft Kel field of theAnglo-Iranian Oil Co. in southwest Iran, for the recovery of casingheadgasoline. It consists in releasing the dissolved gases from the crude bystages, a practice common in many fields, but which, so far as is known, hasnowhere been carried to the extent to which it is employed in Iran. It has beenin use there for nearly nine years, during which time some 200 million barrelsof crude have been handled by the process. This process of gasoline retentionconsists in preventing the greater part of the casinghead gasoline hydrocarbons(the butanes and pentanes) from ever leaving the crude, instead of allowingthem to be vaporized and then recovered from the lighter gases by the usualcompression or absorption processes. Its efficiency is fully equal to thatobtained by the absorption process; its disadvantage is that it increases thequantities of ethane and propane in the crude sent to the refinery, but withthe growing demand for propane this drawback is vanishing.
When casinghead gasoline is recovered as a separate liquid in the Iranianfields, it is blended with the crude, as the only outlet is through therefinery, and the crude-oil pipe line offers the cheapest means oftransportation. It is under these conditions that the retention of the butanesand pentanes in the crude by multistage stabilization is a most attractiveprocess, possessing as it does the following advantages:extremesimplicity,low first cost,easy installation,practically 100 percent operating-time efficiency,no operators required,no water orother services required,negligible maintenance,once established, verylittle routine testing is necessary.
The one essential for reasonably efficient multistage stabilization is that theflowing pressures of the wells should be relatively high; i.e.,' they shouldnot be less than about one-third the saturation pressure of the crude in thereservoir. This is a very general statement, of course, and much depends on thetype of crude and its temperature.
T.P. 1085
Principles of Well Spacing
Authors: Muskat Morris 
Published: June 2014

Although the problem of well spacing is one of the most important involvedin the production of oil, it must be considered at the present time as stillsubject to further development. The published literature on this question is sovoluminous that we cannot enter here into a review of it, except to refer tothe recent papers by L. L. Foley and E. A. Stephenson, where other referencesare cited. However, a decisive and conclusive answer to the problem of wellspacing in any general form does not seem to have been developed. And while weshall be unable to present the desired solution in the present paper, it isnevertheless felt that the material to be given here not only provides thephysical ground work for the ultimate solution, but shows qualitatively theessential factors that enter the well-spacing problem.
Field studies of the well-spacing problem, in which the ultimate recoveriesfrom different fields with different well spacings have been compared, havegenerally suffered from the lack of knowledge as to the similarity of theinherent characteristics of the producing reservoirs being compared, such asthe sand volumes, the sand porosities, the sand permeabilities, the originalreservoir pressures, the presence or absence of gas caps, the presence orabsence of effective water drives, and the economic limits of production ratesat which the various fields were considered to have yielded their ultimaterecoveries. Certainly no one who is evaluating originally the economicsignificance of any oil reservoir would deliberately ignore these phases of theproblem. And it is equally certain that no one would reasonably expect theultimate recoveries from two reservoirs, even with the same well spacing, to beidentical regardless of these other factors.
More reliable results might be expected from comparisons of the recoveriesobtained from different leases with different well spacings, but producing fromthe same reservoir sand. Unfortunately, however, even conclusions for suchstudies may be subject to serious errors.
T.P. 1086
Visual Studies of the Flow of Air-water Mixtures in a Vertical Pipe
Authors: Cromer Sylvan , Huntington R.L. 
Published: June 2014

The need for a clear understanding of the physical nature of the flow ofgas-liquid mixtures in vertical pipes is ever becoming more apparent. This typeof flow is encountered when gas and oil are produced from a well; when water isremoved from gas wells with siphon lines and when liquids are elevated by meansof air or gas lift. Although a number of investigators have published data onthe flow of gas-liquid mixtures, in only a few cases has the experimental setupbeen devised to permit visual study. In the fields of heat transmission, suchas the boiling of liquids and the study of the critical phenomena of thehydrocarbons, researchers have been able to throw additional light onheretofore unexplainable happenings through actual observation in glassapparatus. This investigation was therefore undertaken in order to obtainqualitative as well as quantitative results for air-water flow.

Experimental Apparatus and Procedure
The flow column used in these tests was made of standard 2-in. pipe and wasapproximately 98 ft. in height. Pyrex observation sections 2 ft. long havingthe same internal diameter as the wrought-iron pipe were placed at 14-ft.intervals in the column. The bottom of the tube was cut off square andterminated in the mixing chamber. No perforated nipple or foot-piece of anykind was used. To the top of the column was fastened a semicircular return bendhaving a 4-ft. radius.
The flow column was supported by a standard cable-tool drilling derrick intowhich were built observation platforms at each Pyrex section.
T.P. 1080
Development and Application of Subsurface-pressure Data in Kettleman Hills
Authors: McAllister E.W. 
Published: June 2014

The decision of the California Oil Umpire's office to accept well potentialsestablished from subsurface-pressure data has brought to the attention of manyoperators for the first time the application of such data to productionproblems. This paper reviews the development and application ofsubsurface-pressure data in Kettleman Hills, where these data have been used inproduction work since 1932.
The Kettleman Hills field was discovered in October 1928. The firstsubsurface-pressure surveys were made early in 1932 and by the middle of 1933the two major operators in the field were making routine pressure runs in theirrespective wells. Shortly thereafter, these companies agreed to exchangepressure data, and later a third company entered into the agreement. This madeit possible to analyze the effects upon the reservoir pressure of pastproduction practices, which are discussed in the latter part of thereport.
It is interesting that many of the applications of subsurface-pressure datadiscussed herein were anticipated by C. L. Clarkt and C. B. Kimberlint in areport2 dated March 1933.
Productivity Index
In the majority of individual well problems involving the use ofsubsurface- pressure data, it is necessary to use a factor known as the" productivityindex," which indicates the ability of a well to produce and represents thenumber of barrels of oil or oil and water per day that will enter the well borefor each pound per square inch pressure drop made opposite the producinginterval of the well. The productivity index may be determined from pressureand production data for one or more rates of flow and a static or shut-inpressure surveyor from production and pressure data for two or more rates offlow. Productivity indices may be based upon either net oil or total fluidproduction. All indices referred to in this report are based upon netoil.
The value of the productivity index for Kettleman Hills wells decreasesgenerally with time and it is not uncommon for the index to vary in value atany specific time for various rates of flow. The decline of the productivityindex may be attributed partly to the loss of reservoir pressure. As thereservoir pressure decreases, gas originally in solution is released from theoil, congesting the flow of fluids through the formation and increasing theviscosity and surface tension of the oil; thus the flow resistance of thefluids through the formation is increased, resulting in a decrease of theproductivity index.
T.P. 1303
Characteristics and Application of an Oil-base Mud
Authors: Hindry Horace W. 
Published: June 2014

This paper presents the ingredients composing a type of oil-base mud thathas been successfully used in drilling oil horizons in California, the effectof ingredient concentrations on physical properties, methods of handling at thewell and possible advantages of a waterless drilling fluid with excellentplastering properties.

Introduction
An oil-base mud is a rotary drilling fluid in which oil has been substitutedfor water as the principal liquid ingredient. In recent years such a mud hasbeen developed and used successfully for drilling the oil horizons of wells invarious California fields. There are several types of oil-base mud, but onlythe type that is currently used to any appreciable extent will be considered atthis time.
The oil-base drilling-mud compositions used by Shell Oil Company, Incorporatedhave been covered by several patent applications on which patents are expectedto issue at an early date.
The purpose of this paper is to present data on the fundamental design of themud; the ingredients used and their specifications; the effect of ingredientconcentration on physical properties; the selection of the proper mud; thefacilities needed for handling the mud; and a general discussion on drillingwith oil-base mud.
In view of the early stage of development of oil-base mud, the great number ofvariables, and the almost unlimited possible combinations of these variables, which in turn require extensive laboratory study, there are certainirregularities and omissions in the data presented here. However, it isbelieved that sufficient data are at hand to permit a fairly complete analysisof the characteristics of oil-base muds. In view of the excellent plasteringproperties of oil-base mud when properly proportioned, its use should:minimize the possibility of impairing the natural flow potentialities of theproducing horizon such as that resulting from infiltration of water fromwater-base mudspermit smaller clearances for setting liners, since themud sheath has no appreciable thicknesseliminate the possibility ofclogging the perforations of the liner with thick mud sheathfacilitatethe removal of the mud sheath from the walls of the hole, for its mud sheathhas no appreciable strengthassist in drilling through formations, such as "heaving shale," where water wetting appears to be a source ofdifficultypermit cores to be obtained without contamination from drillingwater.
Fundamental Design of an Oil-Base Mud
In the design of any rotary drilling mud it is necessary to select materialsthat will fulfill the following requirements:act as the liquid medium andregulate the viscosity;impart initial and final plastering properties;give gel strength and structure in order to prevent settling;serve as aweighting material.
T.P. 1322