bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Geophysical History of Darrow Dome, Ascension Parish, Louisiana
Authors: Eby J. Brian , Harkins T.I. 
Published: June 2014

Abstract
This paper outlines the geophysical investigation of the area covering theDarrow salt dome, Louisiana. Surveys with the refraction seismograph andtorsion balance failed to disclose the dome, but reflection dip shooting wassuccessful and was confirmed by later drilling.

Introduction
The Darrow salt dome and oil field lies in western Ascension Parish, Louisiana, on the outside of a sharp bend and on the east bank of theMississippi River. The dome occurs about 30 miles south of Baton Rouge and 80miles northwest of New Orleans. Its geology, shape and structure have been ablydescribed in detail by Carroll E. Cook and, except for the general features, will not be repeated here. The purpose of this paper is to record some of theinteresting and pertinent geophysical data contributing to the discovery of thedome and eventually the oil field.
The salt dome is circular in outline and comes to within about 4625 ft. ofthe surface. At this depth the diameter of the salt plug is approximately 4800ft. The dome has only a thin cap rock of less than 75 ft.
Some oil has been found and is being produced in Miocene sands above the caprock, but most of the field's production comes from a narrow ring of wells aroundthe east and south flanks of the dome. Producing horizons on the flank arefound at 5670 to 5840 ft. in the Miocene and 6890 to 6985 ft., 7028 to 7060 ft.and 8260 to 8270 ft. in the Oligocene. The deepest well that has been drilledis the Humble Oil and Refining Company's Community B-5, on the south flank ofthe structure, which reached a depth of 10,013 feet.
The size and shape of the field and the area of production are indicated onFig. I. The line showing the area of production encloses all wells nowproducing and all abandoned producers, both on the top and flank of the dome.This line of production is shown on all subsequent geophysical maps as a directmeans of comparing the early geophysics to later drilling development.
T.P. 1495
Waters from the Frio Formation, Texas Gulf Coast
Authors: Jessen F.W. , Rolshausen F.W. 
Published: June 2014

Abstract
It is the purpose of this paper to present data on brines occurring in the Frioformation of the Texas Gulf Coast, and to show how their composition varies,with depth below the surfacewith depth below the top of theformationalong the approximate strike.
The brines vary in chloride content from 3,180 to 73,000 p.p.m., though theaverage salinity of the salt waters is shown to vary with total depth; theconcentration being 35,000 to 40,000 p.p.m. at 3500 to 5500 ft., slightly lessthan 50,000 p.p.m. chloride at 5500 to 6500 ft. and average 38,000 to 40,000below 6500 feet.
From the analyses available, it appears that the highest concentration of saltsoccurs in the upper 300 ft. of the formation, while lower salinity is foundwith increasing depth below this point.
The salt waters from wells in Starr County show less concentration of dissolvedsalts than in any other group of wells farther north along the strike.
In all, 116 analyses from 63 fields and 14 wildcats, from depths ranging from1300 to 11,400 ft. below the surface and from 2 to 3240 ft. below the top ofthe Frio, are recorded.

Introduction
Brines have been studied for many years in' an attempt to solve some of thegeologic and production problems associated with the production of oil and gas.One practical application of study of water analyses is the correlation ofwaters occurring above, in, or below the producing sand in the same field orthroughout the same formation.
The Frio formation, the series of sands and shales occurring below theMarginulina zone and above the Vicksburg, is.one of the major oil andgas-producing formations in the Texas Gulf Coast. Fossils are rare or absent inthe upper Frio throughout most of the area. When available, cuttings and cores, and electric logs were used to determine the top of the Frio. A change inlithology was used to determine this point in most of the wells, and fossilswere used in some of the deep wells.
It is realized that a change in lithology is not perfect for correlationpurposes over long distances and some of the trends may be influenced by theinability to differentiate between the nonfossiliferous Marginulina zone andthe Frio. It underlies virtually all the area shown on the accompanying map(Fig. I). Although it is not productive in the up dip facies, it has beenexplored to a limited degree below 12,000 ft. Furthermore, toward the coastline future drilling to deeper depths should encounter this formation.
Although thousands of wells have penetrated or drilled entirely through theformation, very few water samples have been secured from the many sandsoccurring in this formation and analyzed.

Previous Investigation
No previous published study has been made of the chemical composition andconcentration of waters from the Frio formation.
T.P. 1729
A Method of Drilling in Deep Water
Authors: Gross Henry Emmett 
Published: June 2014

Abstract
The waning supplies of domestic petroleum make it desirable to develop oilfields in new provinces, among the most attractive of which appear to besubmarine deposits; notably, in the Great Lakes. The author's portable openfoundations and means of oil-field development are presented. His designs for30 to 100 ft. of water, and for 100 to 600 ft., which offer possibilities ofcompletely exploiting the continental shelves, are set forth. It is emphasizedthat foundations must be of sufficiently low cost to be attractive. A methodfor overcoming ice hazards is outlined.

Introduction
New sources of petroleum and natural gas are beneath large bodies of watersuch as the Great Lakes, except Lake Superior, and ultimately the continentalshelves.
It is now particularly desirable to exploit the Great Lakes because:there is an acute shortage of petroleum and natural gas in the surroundingarea;the Lakes are far inland and safe from enemy raidersthey offerthe shallowest possible sources remaining in this countrythe water isnot as rough as in the open seas.
The one discouraging condition, floating ice in the winter, should offer noproblem.
In the Great Lakes, four places appear attractive for prospecting for oil:the western end of Lake Eriethe northwest half of Saginaw Baythe east side of Lake Michigan between Benton Harbor and Ludingtontheshallow south end of Lake Huron.
The title to submerged lands beneath navigable waters of the United Statesis owned by the various states. The boundaries are established. Leasing wouldhave to be from the states, but before mineral could be extracted, approvalmust be obtained from the War Department.

Methods of Development
The shallower parts of such small bodies of water as the western end of LakeErie, Lake St. Clair or Saginaw Bay, could be prospected and drilled by thesubmersible barge of Giliasso, one of which can keep a single string of toolsrunning for about eight months of the year. Some of the deepest wells have beendrilled from submersible barges in the bays and bayous of the Gulf Coast. TheCedar Point field in Galveston Bay was developed by barge drilling. This methodat present is limited to water less than 10 ft. deep, and is not suitable inopen water like that offshore in the Gulf of Mexico or the Pacific Ocean.
T.P. 1722
Natural Potentials in Well Logging
Authors: Mounce W.D. , Rust W.M. 
Published: June 2014

Abstract
The almost universal acceptance of electrical logging by the petroleum industrycalls for a critical examination of the physical bases of the common methods.This is particularly needed for the natural potential log. The conventionalexplanations are based on the phenomena of electro filtration and electroosmosis. However, experimental data show that they fail to give a basis that isquantitatively sound. Moreover, they lead to interpretations of details ofelectrical logs that are erroneous.
It was found experimentally that when a plug of shale is placed in a chain ofdissimilar electrolytes, a current flow results. Experiments on oil-well coresand fluids similar to those existing in wells show that potentials are set upwhich are in reasonable agreement with those encountered in electrical logging.Doubtless other sources of potential are important but this explanation notonly accounts for much of the potential but also clarifies some fairly familiarexamples of misinterpretations.

Introduction
The extraordinary value of electrical well logging as a tool for petroleumengineers and geologists is now so universally recognized that it is notnecessary to point out the ways in which it can be useful. It is sufficient tomention only the saving that has resulted from the elimination of much coringthat would have been necessary under former practices and the considerableadditions to reserves resulting from the discovery of sands missed incoring.
Paradoxically, the very remarkable success that has resulted from theapplication of electrical logging to correlation and completion problems hascost some of its most consistent users dearly. 1 The fact that some operatorshave placed unwarranted faith in erroneous interpretations of electrical logsdoes not reduce the value of the logs. It should, however, make one pause longenough to ask why experienced users should be misled. The answer to thisquestion is not hard to find. In nearly every case, the fault has beenoversimplification. This is illustrated very aptly by the familiarinterpretation and theory of the natural potential log.

Recording and Interpreting Logs
The natural potential log is extremely simple to record precisely enough forall present-day uses. One needs only an electrode, a cable to lower theelectrode through the drilling mud, a recording meter and a surface groundconnection. The electrode can be elaborate but need not be. A simple brass rod2 in. in diameter and 2 or 3 in. long is quite satisfactory. The cable need notbe particularly well insulated, nor need it have a very low resistance.
T.P. 1626
Postwar Uses of the War Emergency Pipe Lines for Petroleum Transportation
Authors: Swigart T.E. 
Published: June 2014

The two War Emergency Pipe Lines were built by the United States Governmentto meet the serious transportation shortage caused by the diversion of thetanker fleet from the Gulf to East Coast run. The estimated 140-million dollarcost of these pipe lines approximates that of two battleships; however, becausethe lines have been so widely publicized as national defense measures, andfurther because their utility is so closely linked with the daily convenienceand welfare of the civilian population, their importance in the public mind isprobably magnified beyond that of two ships of the line. Thus, there may bestrong demand by the public, Congress, and the executive branch of theGovernment to maintain these lines in operating condition after the war.
Probably the simplest means of maintaining them in good condition is tocontinue them in operation. In keeping with American principles of privateenterprise, it will be desirable if they can be shown to have a place in theeconomic life of the country and can be operated by industry.
The most obvious use for the lines would be the movement of crude andproducts from Texas to the East Coast; for this business they will have tocompete with tankers. Their location enables them also to handle movements intoDistrict 2, for which business they must compete with existing privately ownedpipe lines and with barges. This paper attempts to analyze economic factorsthat bear on the use of these two big lines in the postwar period and todevelop through estimates the competition they may offer to other forms oftransportation.
The writer has purposely refrained from making recommendations as to theutilization of the War Emergency lines for petroleum transportation because itseems likely that prospective purchasers would be one or more operating oilcompanies, each of which would analyze the utilization of the lines in light ofits own business requirements. It is doubtful whether the lines would beacquired by a non-petroleum financial group for operation as commercialcarriers because interstate common carriers are prohibited from contracting tofurnish services to shippers, a restriction that implies that carriers, inturn, cannot expect to obtain guarantees of traffic from independent shippersin great enough volume to ensure return of their investments.
T.P. 1757
Selective Acidizing and Permeability Determination by an Electrical Method
Authors: Hefley Danna G. , Fitzgerald P.E. 
Published: June 2014

Abstract
An apparatus has been developed which permits selective acidizing of producingformations and determination of the relative permeability of a formation byfluid injection. This apparatus, known as the "Electric Pilot," is anelectrical fluid-interface locator, the electrical circuit of which iscompleted when the electrodes in the well are in contact with a conductivefluid, but is not completed when immersed in a nonconductive fluid. Results aregiven for a number of typical acidizing applications in which the interfacelocator was used to control the acid. Description of the method used in makinga permeability survey and the data obtained are also included.

Introduction
Early in the development of the acidizing industry it was recognized that oneof the most important problems to be solved in the chemical treatment of anywell was the determination of what part of the exposed section in the wellshould be treated and the selection of the technique that would insuretreatment of the desired section.
One of the first techniques adopted for assisting in proper placement of theacid, which is still widely used, is the method of confining the acid to theproducing section by means of a column of oil, which is known as the Carrmethod of treatment, named for its inventor. In the Carr method it is notpossible to selectively acidize a specific horizon in a multiple pay zone, somany improvements and modifications of the basic Carr technique were devised toaccomplish this result.
In order to overcome the possibility of the acid entering an undesirablesection at the bottom of the well, organic gel plugs were introduced into thebottom of the well, which served to halt the entrance of the treating solutioninto these zones. These chemical gels later liquefied because of bacterialaction and were removed from the well with the produced fluid.
In fields where a gas cap existed, as in the Goldsmith field of Ector County, Texas, it was imperative that a treating technique be evolved that wouldconfine the acid to the oil-producing zone below the gas cap. By so doing theoil-productive capacity of the wells could be improved without greatlyincreasing the gas production and this would lower the gas-oil ratio of thewell. The technique employed 4 to achieve this effect utilized two pumps, onefor pumping the chemicals down the tubing, the other to simultaneously forceoil down the annular space to confine the acid to the oil pay, thus preventingthe chemicals from entering the upper gas-bearing zones.
Experience has indicated that gas wells and certain types of oil wells respondbetter to "stage treating." This technique utilizes the introduction ofa certain volume of acid and then allows the well to "clean tip" beforeintroduction of the next and usually successively larger stages. Where suchmethods are employed steps must be taken to keep a disproportionate share of, the acid from entering the most permeable and previously treated zones.
T.P. 1604
Water Permeability of Reservoir Sands
Authors: Johnston Norris , Beeson Carrol M. 
Published: June 2014

Abstract
For many years the permeability of reservoir sands has been measured by flowingair through a cleaned and dried core sample. This differs from the truereservoir permeability in one important respect: the rock particles in thereservoir are surrounded by interstitial water, not air, and their physicalshape and condition of hydration are greatly dependent thereon. Permeability asdefined must be measured with a single-phase fluid. Since no means exist forremoving the oil and gas from a core sample by simply flowing water through it, the sample must be cleaned and then resaturated with water before testing. Thepresent discussion attempts to show that after the cleaning process aconsiderably different permeability is determined with salt or fresh water thanis obtained with air. The postulate is made that the salt-water permeability isprobably closer to the true reservoir permeability than is the measurement withair. This is discussed in relation to both physically possible and economicallyfeasible measurements. Data on more than 1200 core samples are given to showthe nature of the effects observed, and a plea is made for others to considerwater permeability measurements as a routine necessity, eventually replacingair permeability in regions where the differences are great.

Introduction
Permeability is defined as "a measure of the capacity of a porous medium totransmit? fluids, when there is no interaction between the solids and thefluid."
T.P. 1871
Prediction of Conditions for Hydrate Formation in Natural Gases
Authors: Katz Donald L. 
Published: June 2014

Abstract
Charts for predicting the pressure to which natural gases may be expandedwithout hydrate formation have been prepared for gases of even gravity.Pressure-temperature curves for hydrate formation were established for gaseshaving gravities from 0.6 to 1.0. These curves and the thermal behavior of thegases during free and adiabatic expansion were used to prepare the charts forestimating the permissible expansion of natural gases without hydrateformation.
The problem was solved by L. F. Albright, W. 'T. Boyd; J. J. McKetta, G.Martin, F. Poettman, and A. P. Snyder, who are first year graduate students inthe department of Chemical and Metallurgical Engineering at the University ofMichigan. This paper is essentially a summary of their results.
Prediction of Conditions for Hydrate Formation in Natural Gases
Each natural gas under a given pressure will form solid hydrates at acorresponding temperature provided sufficient water is present. The temperatureof natural gases below about 5000 lb. per sq. in. decreases when the gases areexpanded freely. This decrease in temperature may cause the expanding gas toenter the region of temperature and pressure at which hydrates will form. Thefinal pressure to which a natural gas may be expanded without hydrate formationdepends upon the initial temperature and pressure and the gascomposition.
This paper presents charts that give the final pressures to which gases ofgravity 0.6 to 1.0 at given initial temperatures and pressures may be expandedwithout formation of hydrate.
Hydrate-Forming Temperatures and Pressures as a Function of Gas Gravity
Experimental data of pressure versus temperature, at which solid hydrate willform, provided sufficient water is present, are available for a series ofgases. A method of predicting the pressure-temperature curve for a given gascomposition has been reported. The solution to this problem requires that thesecurves relating pressure to temperature be established for gases of givengravities.
T.P. 1748
Fractional Analysis of Well Effluents to Trace Migration of High-pressure Reservoir Gas
Authors: Valby E.P. 
Published: June 2014

Abstract
A method is presented in which the hydrocarbon weight fractional analyses ofthe well effluents from a true gas-cap-portion well and a true dark-oil-ringwell furnish the basic data for determining the properties of any mixture ofproduction from the two sources. The effect of injected gas on these propertiescan be computed. Comparison of similar properties of a given well effluent tothe properties of mixtures of the basic well effluents will give the relativeamounts of production from the two sources and injected gas.

Presentation of Problem
Oil fields having an area of gas-cap, or light-oil production, over thedark-oil area present a problem of increasing gas oil ratios during theproduction of an oil well. The use of pressure maintenance in a field such asabove, or a cycling project, wherein residue gas from an absorption plant isinjected into the reservoir, adds to the problem, because a part of theincreased gas-oil ratio may be due to the production of injected gas. Theusefulness of a means to determine the amount of injected gas in a welleffluent led to the development of a method in which well effluent analyses ofa true gas-cap-portion well and a true dark-oil-ring well furnish the basicdata needed to determine Whether injected gas of a known composition is presentin a given well effluent.

Development of Method
The method presented herein is based upon the principle that if two fluids, orwell effluents, having different properties are mixed in known proportions byweight, the properties of their mixtures can be computed. Conversely, if thesebasic data are known, the properties of a mixed well effluent can be used tocompute the relative amounts of each type of well effluent in the mixture. Aconvenient way of making these computations is to have the fractional analysesof the base well effluents and mixtures expressed in weight fractions. Themathematical equations expressing the properties of mixtures will be developedfor a two-component system consisting of the well effluents from the dark-oilring and the gas-cap area. The added effect of injected gas, a third component, will also be developed.
The following assumptions have been made in developing the method:The gas-cap and dark-oil fluids exist initially in separate portions of thereservoir.The fluids in each portion exist in a single phase at pressures above thesaturation pressure for the dark-oil fluid.The composition of each fluid is substantially constant throughout itsrespective portion of the reservoir.Changes in reservoir pressure and temperature will not change thecomposition of the fluid entering the well bore.The injected gas displaces original gas-cap fluid 100 per cent.
T.P. 1873