bluuebunny/crossref_metadata_2025_split huggingface dataset:
Water-flooding in the Mid-Continent
Authors: Fancher George H. , Barnes Kenneth B. 
Published: June 2014

With the advent of water-flooding into active commercial usage in half adozen areas in the Mid-Continent, the process passes the experimental stage andjoins other methods and processes now in use which have been found suitable inone oil field or another in securing a more profitable production than hasexisted heretofore. The use of the air-gas lift, acidization, pressuremaintenance and repressuring have presented their problems in economics andengineering during their introduction and extended application. When a newfield is discovered or attention is turned to an old producing area in whichthese methods have not been considered, it is to be expected that theseproblems again arise. While some information i; available as to the resultsobtained by water-flooding in a few localities in the Mid-Continent, theextrapolation of the sand data on which the results are based, for evengeneralized use in other areas and fields in the region, is hazardous. It isprecarious to assume that the same physical condition will obtain in a sandover more than small, special areas.
This paper is concerned with a brief presentation of such data as are availableto the authors on existing operations, a survey of the region and extent towhich application of the method seems most likely to be made, an estimation ofthe crude reserve existing for such operations, suggestions as to theimportance of core analysis in guarding against uncontrolled floods. and itsusefulness in predicting ultimate recoveries, and comment on some of theeconomic phases involved. These subjects, as concerned with water-flooding inthe East (notably Bradford, Pennsylvania), have been discussed in detail in theliterature and are generally well known. Especially is this true of discussionsof the mechanical equipment and various lease layouts and development patternsfor water-flooding.
Chemical Methods for Shutting Off Water in Oil and Gas Wells
Authors: Kennedy H.T. 
Published: June 2014

The fact that intrusion of water into oil wells can be prevented by treatingthe sand adjacent to the well seems to have been only recently recognized. Swan1 mentions the process of solidifying naphthalene in strata. R. Van A. Millsrecommends the use of materials such as sodium silicate and sodium carbonate, which react with oil-field water to form solid plugging agents.
When a well is drilled in a new field the oil sands are found essentiallydevoid of water (Fig. 1). Unless a completely impermeable break exists over wide areas in the field, no water is found above the lower limit of theoil zone and no oil is found below the upper limit of the water zone. Afterconsiderable oil has been taken from the well, however, it is almost universalexperience that water intrusion occurs. This intrusion may be of two kinds. Thewater may follow a path parallel to the bedding planes of the producingformation through loose streaks in the pay sand, as shown in Fig. 2, or thewater level of the field may rise and enter the well by coning (Fig. 3). Waterentering from the side is called "edge water," and that coming in fromthe bottom is called "bottom water."
Experiments on Flow of Fluids through Sands
Authors: Plummer F.B. , Woodward J.S. 
Published: June 2014

The measurement of the rate of flow of liquids through sands dates back to1856, when H. d' Arcy, a French physicist, carried out his classic experimentson the flow of water through sand layers. The earliest recorded data onrelationships of pressure to flow of fluids through porous rocks in thiscountry are those of Newell in 1885. The first comprehensive studies of flowwere made in 1898 by King, who measured the rate of flow of water and airthrough consolidated and unconsolidated sands and published the results. From1900 to 1920 there appears to have been little interest in permeability.
In 1920 the increase in demand for oil led the U. S. Bureau of Mines to begin aseries of experiments to determine subsurface relationships of oil and waterand the characteristics of their flow. Mills studied the relationship of flowof liquids to texture and structure of the sands, and Melcher in 1925 made aquantitative study of effect of changes in pressure on rate of flow of crudeoil through Oklahoma oil sands. Since 1930 the importance of flow measurementsto production of oil and gas has been emphasized by a large number of excellentinvestigations. Among these the works of Fettke, Barb, Cloud., Nutting, Botset, Nevin, Tickell, Fancher, Lewis and Barnes, Moore, Schilthuis and Hurst, andWyckoff, Botset and Muskat have contributed much to our knowledge of thetechnique of permeability measurements and to the laws of liquid and gas flowthrough porous sands. The application of their work has led to theestablishment of laboratories for measuring the permeability and porosity ofoil sands by most of the large companies. All the investigations, except thoseof Wyckoff, Botset and Muskat, and Moore, Schilthuis and Hurst deal with linearflow; that is, flow in a more or less straight line through a givencrosssectional area of sand.
An Equilibrium Theory of Proration
Authors: Pogue Joseph E. 
Published: June 2014

Any mechanism, either natural or artificial, for regulating the functioningof a given unit in the general economy must operate toward the maintenance ofequilibrium if it is to survive. The petroleum industry, concerned as it iswith the production of a natural resource of specialized character, issurrounded not only by the economic factors common to other industries but byan extra set of unique elements centering about the fugitive character of crudepetroleum under conditions of competitive development. The term equilibrium, therefore, so far as the oil business is concerned, involves a combination ofeconomic and physical factors: the first set having to do with supply, demand, costs, profit margins, purchasing power, and the like; and the second, withunderground pressures in oil pools, efficient rates of extraction, and allother aspects of engineering that may be summarized by the familiar term"conservation." The two categories, in fact, are not as clearly dividedas the foregoing statement would imply, for in practice it will be found thatthe economic and physical aspects have a pervasive interaction andinterrelationship.
If the development of the petroleum industry in the United States isexamined from its inception in 1859 down to the present, it will be found that, beginning about 11 years ago, a new mechanism for regulating the production ofcrude petroleum made its appearance. Prior to this recent period, theproduction of this raw material was determined by competitive forces operatingwithout outside restraints. At present the output of crude oil is subjected tosupervision by regulatory bodies in most of the oil-producing states, whichimpose upon the operators certain conditions having to do with the manner andrates of production. Thus, in the space of a decade, the mechanism forproducing crude oil has changed from an automatic to a designed procedurecalled proration. And in its short history this method has been marked by arapid evolution in its nature and incidence, with progressive changes stillunder way.
T.P. 904
The Wilmington Oil Field
Authors: Bartosh E.J. 
Published: June 2014

In the brief period from November 1936 to September 1937, the Wilmington oilfield developed far beyond all expectations. Decline in some wells appears veryrapid, but it is too early to draw definite conclusions, as the majority ofwells are maintaining very large and steady output. Heavy curtailment in thecentral area, which has developed the largest wells, makes it impossible toarrive at a satisfactory estimate of decline.
The field is producing oil from the Repetto (lower Pliocene) and Puente (upperMiocene) formations, which are of the same age as formations producing atTorrance, EI Segundo, del Rey or the marginal fields of the Los Angeles Basin.All of these fields are underlain by schist. The Long Beach field, northeast of Wilmington, is productive throughout 3000 ft. of Repetto-Pliocene series andalso approximately 3000 ft. of Miocene formations, whereas at Wilmington only 700 to 800 ft. of Repetto and 2500 ft. of Miocene formations contain oil andgas.
This paper gives a brief summary of the history and development of the field toSept. 15, 1937, showing the subsurface conditions as they exist with the fieldonly partly developed.

History of Development
The Wilmington oil field, 20 miles due south of Los Angeles, adjacent to LosAngeles harbor and about midway between the cities of San Pedro and Long Beach(Fig. 7), was producing oil as early as 1932 and only came into prominence as amajor oil field of Southern California in the fall of 1936, when the GeneralPetroleum Corporation of California completed Terminal well No.1 from the upperMiocene, at a depth of 3625 ft., for a daily production of 1500 bbl., 20?gravity A.P.L, thereby establishing discovery of the Terminal zone.
El Segundo Oil Field, California
Authors: Porter L.E. 
Published: June 2014

El Segundo field is about 14 miles southwest of the central portion of thecity of Los Angeles, immediately adjacent to the town of EI Segundo and theStandard Oil Company's EI Segundo refinery site. The field is served andbisected by several major highways connecting the beach cities on the west sideof the Los Angeles Basin. The exact location of the field and its position withrespect to other producing areas is shown on the map covering this portion ofthe Basin (Fig. 1).
The Republic Petroleum Co; discovered the first commercial production in thearea when it completed its EI Segundo No.1 (sec. 18, T. 3 S. R. 14 W.) at adepth of 7402 ft. on Aug. 24, 1935, flowing at the rate of about 400 bbl. perday, 28? gravity oil. The producing horizon in this well consists of about 72ft. of conglomerate and schist conglomerate situated below the nodular shale.(Miocene). The true (or solid) schist (Franciscan) was encountered andpenetrated some 20 ft. in the bottom of the hole.
This paper gives a report on the history of development and oil production todate, and also submits the writer's interpretation of structural conditions asdetermined from such development. The limited development, together with thecomplex and variable nature of the producing horizon, makes any interpretationof the structure at present only tentative, and any forecast for a given wellextremely hazardous

History of Oil and Gas Production
The EI Segundo field has produced approximately 1,920,000 bbl. of oil. It has27 producing wells and 14 drilling wells or locations. The present daily rateof production is about 13,400 bbl. The production history of the field to dateis shown in Table 1. The principal companies operating or owning leases in thisfield are: Caminol Company, Geo. F. Getty, Inc., Ohio Oil Co., RepublicPetroleum Co., Pacific Western Oil Corporation, Royalty Service Corporation, Richfield Oil Corporation; Standard Oil Company of California, The TexasCompany, Union Oil Company.
Ten Section Field, Kern County, California
Authors: Wyatt H.T. , Baptie A.S. 
Published: June 2014

The Ten Section field is approximately 10 miles southwest of Bakersfield, Kern County, Calif. (Fig. 1). There is no surface evidence of the existence ofthe Ten Section structure, which subsurface exploration has shown to be agently folded, anticlinal dome. Regionally, this field occurs as a fold in thedeeper beds of the gently rolling floor of the San Joaquin Valley. It is on theeasterly slope of the valley, its position with relation to the axis of thissyncline not having been determined.
The field was discovered by Shell Oil Co. with the completion of well Stevens A-I, on June 2, 1936, at a depth of 7888 ft.
Calculation of Equilibria in Hydrocarbon Mixtures
Authors: Buckley Stuart E. 
Published: June 2014

The application of hydrocarbon equilibrium data to various problemsencountered in refining and in natural gasoline recovery is an old and wellestablished practice. Both generalized data and data on? specific hydrocarbonsystems have been made available by a number of investigators. More recentlysuch data have been applied to the relations governing the separation of oiland gas both in the reservoir and at the surface. Most of the applications toproduction problems, however,. have been based upon examinations of surfacesamples of oil and gas. This paper describes a technique that has been usedsatisfactorily in a number of cases to calculate directly from the hydrocarbonanalysis of and auxiliary laboratory data on a subsurface sample of thereservoir fluid the behavior of the oil and gas during the various stages ofseparation at the surface incident to production.

Types of Information Calculated
The system of calculations is not designed to supplant field data, but ratherto correlate with them laboratory data obtained under controlled conditions inorder to obtain a more complete and exact picture than usually is possiblethrough the use of field data alone. The chief advantage of the calculations isthe possibility of their use at a minimum of both time and expense to determinecompletely the effect of any possible operating technique upon each of thefollowing:The gas-oil ratio resulting from liberation of the dissolvedgas;the composition and gasoline content of the liberated gas;thecomposition and gravity of the residual oil;the amount and composition of the gas liberated upon flashing the oil from the separator to the stock tank;the shrinkage of the oil in passing from the reservoir to the stocktank.
This information is frequently essential to the correct determination of theadvisability of installing a natural gasoline plant, to design such a plant totake care of seasonal production, and to determine the optimum separatorpressures to carry in various parts of a field.
T.P. 872
Connate Water in Oil and Gas Sands
Authors: Schilthuis Ralph J. 
Published: June 2014

Several investigators have reported evidence of the existence of native orconnate water in oil-and-gas-bearing strata. Both water and salt have beendetected in cores of oil sands that yielded oil and gas exclusively whenproduced. Electrical logs often reveal unexpectedly low resistivity through oiland gas sands, indicating the presence of some material that is a considerablybetter conductor of current than oil and gas. Furthermore, calculations of theoil and gas content of reservoirs based upon production and reservoir-pressuredecline data indicate appreciably lower values than are arrived at under theassumption that the pore space is occupied completely by oil and gas.

Origin and Occurrence of Connate Water in Oil-and-Gas-Bearing Formations
The view has been expressed, 1O–15 and is generally agreed upon, that theexpulsion of oil and gas material from source beds and the subsequent migrationand accumulation occurred in the presence of salt water. As the strata thatusually form reservoirs for oil and gas were laid down by, or in the presenceof, ancient seas, the pore space within the strata must have been saturatedwith salt water before the entrance of the oil and/or gas. Thus, theaccumulation of oil and/or gas in the upper regions of structures suitable forreservoirs must have required displacement of the connate watertherefore.
In the absence of any forces other than gravitational, it would be expectedthat the displacement of the connate water out of the zones finally occupied bygas and oil would be complete, and that the vertical distribution 'of gas, oil, and water in a reservoir would be strictly in the order of their densities.Apparently, however, surface and interfacial forces that will not permitcomplete segregation of the fluids are active within the capillary spacescomprising a reservoir. The effects of these forces on both accumulation andproduction of oil and gas have been the subject of study by a number ofinvestigators.
T.P. 869
Influence of Connate Water on Permeability of Sands to Oil
Authors: Dunlap Eldon N. 
Published: June 2014

Recently the producing branch of the petroleum industry has shown aconsiderable and growing interest in the quantitative determination of thewater, oil, and gas content of cores as it relates to estimation of reserves, to providing a basis for judging as to the feasibility of applying varioussecondary-recovery and pressure-maintenance processes, and in general to theoperation of producing properties. For years it has been known that oil, gasand water coexisted in the pores of many semidepleted oil measures. It is nowgenerally believed that oil-bearing beds contain connate water in amountsvarying up to 50 per cent of the pore space. However, only lately has reliabledirect evidence of the extensive occurrence of connate water in oil sands beenpublished. Very little work has been done to ascertain the effect of this wateron the productivity and ultimate recovery of oil from wells. It was the intentof this research to study the influence of interstitial water on the flow ofoil through unconsolidated sands, with the hope that the results could beapplied qualitatively to the flow of oil in underground reservoirs partlysaturated with water.
Obviously, ultimate recovery estimates based on the void volume of thereservoir will be in error unless a correction is made for the volume of waterthat occupies a portion of the effective pore volume of the reservoir.Evaluation engineers in the past have applied arbitrary saturation and recoveryfactors that may inadverently have compensated for the failure to considerspecifically the water content. Nevertheless, the evidence available indicatesthat these factors need revising if each is to be independently correct andtruly representative.
Although the fact that the connate water renders part of the pore volume of thereservoir incapable of containing oil is of primary importance to the operator, it is also to his interest to know to what extent the presence of varyingamounts of interstitial water influences the permeability of the sand tooil.
T.P. 874
Flow of Oil-gas Mixtures through Unconsolidated Sand
Authors: Reid L.S. , Huntington R.L. 
Published: June 2014

The study of the flow of oil and gas mixtures through oil-bearing formationshas received special attention from the petroleum industry within the past fewyears, and has resulted in a series of research projects based upon variousphases of the flow of heterogeneous fluids through porous media.
Obviously, the low cost of producing oil during the flowing life of a wellmakes it desirable to obtain production by natural flow as long as possible andto effect a maximum recovery of oil and gas by the utilization of reservoirenergy through efficient methods based upon a thorough knowledge of reservoircharacteristics. Despite the extensive research that has been carried out, there is little information available on the behavior of oil and gas mixturesflowing through reservoir formations. This makes it impossible to predeterminethe optimum operating conditions for flowing wells.
A differential pressure must exist in the reservoir in order to induce flowtoward the well. It is a well established fact that with homogeneous fluids therelation of pressure drop to linear distance traveled is a straight linefunction as long as the flow is viscous. However, in regard to gas saturatedoils, a number of investigators have reported that the flow characteristics arematerially altered as some of the lighter hydrocarbons are liberated from theoil to form gas while the fluid passes through the reservoir.
Most of the work done has been concerned primarily with steady-state flow ofliquid-gas mixtures cloud has studied the effects of saturating crude petroleumoils with various gases, together with the resultant pressure gradients understeady flow conditions, noting that unsaturated oils flowed faster and yetmaintained lower pressure gradients than saturated oils.
T.P. 873
Development and Production Problems in High-pressure Distillate Pools
Authors: Foran E.V. 
Published: June 2014

Among the many newer disclosures that have accompanied the petroleumindustry's progressively deeper exploratory drilling is the increased frequencywith which the operators are encountering reservoirs of which the products atthe time of discovery exist wholly or predominantly in the gas phase. Thepopular term "distillate pool" is most often used within the industrywhen referring to this type of reservoir, and in this paper the term is used inthat sense. These pools have been observed in many different surroundings. Insome places the entire reservoir is filled with the wet gas containing itswater-white condensible products in the gas phase but apparently with no darkoil or other hydrocarbon liquids in the reservoir. The 8200-ft. horizon in theBig Lake field in West Texas is a good example of this type. At other placesthe wet, or distillate-bearing, gas may form a large gas cap directly overlyingand in contact with an extensive reserve of dark oil. Oklahoma City, KettlemanHills, the 8500-ft. horizon in the Big Lake field, and many others are examplesof this type. There are also many places in which the wet distillate-bearinggas fills nearly the entire reservoir space, while the dark oil occupies only anarrow, band-like zone, which marks the boundary of the reservoir along itslowest productive contour.
The heavier components of these deep pool gases are generally water white incolor, a large portion of which are condensible in a conventional oil and gasseparator, when operated under pressures of the order of 400 to 800 lb. per sq.in. Although the water-white products recovered in the separator sometimes haveend points of 6500 F. and higher on standard Engler distillation, they occuronly in the gas phase in the reservoir. It is entirely possible that even somesmall amounts of dark colored reservoir components may occur in the gas phasewhen the temperature is 3000 F. and pressures exceed 6000 lb. per sq. in. Closeapproaches to these conditions have been encountered in the deepest producingwells. The condensible content of the deep reservoir gases of the many poolsthat have been tested or produced to date shows a wide variation in bothcondensible content, per 1000 cu. ft. of gas, and physical character.
T.P. 1023