bluuebunny/crossref_metadata_2025_split huggingface dataset:
Reduction of Residual Oil Due to the Presence of Free Gas During Water Displacement
Authors: Stewart F.M. 
Published: February 2020

Petroleum Conference on Production and Reservoir Engineering, 20–21 March, Tulsa, Oklahoma

Introduction
It has been proved that in many cases the presence of a free gas phase will reduce the residual oil saturation obtained in the displacement of oil by water. This holds for both natural water drives and imposed water floods. For floods at constant pressure, the effects of the presence of free gas on waterflood behavior may be evaluated from tests on short core samples. However; it may be desired to estimate these effects when the results of appropriate flow tests are not available. The purpose of this note is to assemble available information from several sources to aid in doing this.
The discussion in this note pertains to the displacement of oil by water under conditions of essentially constant pressure, and with the pressure differential across the oil bank and flood front small compared to the flooding pressure. The beneficial effect of free gas in the displacement of oil by water comes from the establishment of an immobile or trapped gas saturation at the flood front. Evaluation of this effect in a particular case requires the estimation of [1] the trapped gas saturation maintained at the flood front, and[2] the reduction in residual oil saturation caused by this trapped gas.

Trapped Gas as a Function of Initial Gas
It is an accepted concept that, under the pressure conditions prescribed, some portion of any initial free gas is trapped in the oil bank pushed ahead of the displacing water. If a continuous mobile gas phase existed prior to arrival of the oil bank, part of the initial mobile gas is displaced by the oil bank, leaving a residual immobile trapped gas saturation. [It is assumed that pressure remains fairly constant such that gas solubility and compressibility effects are negligible.] The trapped gas, being a nonwetting phase, is in discontinuous globules or filaments. Within the oil bank ahead of the displacing water, oil fills up the pore space around the trapped gas, except for that portion occupied by connate water.
The relationship between initial and trapped gas saturation obtained from tests on various materials is given in Fig. 1. These data are from References 1, 2, and 3. Pertinent information on the tests is in Table 1. Obviously the relationship depends on the core material and fluid properties. For the same core material and initial gas saturation, less gas is trapped by the more viscous oil; this is shown by the variation of the points plotted for tests 2aand 3a from the line for tests 2 and 3.
For initial gas saturations of less than 10 per cent, trapped gas as a percentage of initial gas saturation ranges from 60 to 100 per cent. The percentage on each test and for the group decreases as initial gas saturation increases [Fig. 1 and Table 2]. This trend is expected, and it means that the greater the initial mobile gas saturation, the larger the portion of the gas which is displaced ahead of the oil bank.
Oil and Gas Securities
Authors: La Piere Gilbert H. 
Published: February 2020

Annual Meeting of the American Institute of Mining, Metallurgical and Petroleum Engineers, 14–18 February, New York City

Recent Trends in Oil
Since May 1, 1957, oil shares have lost their rank of leadership with investors. Until recently, the public had invested more money in oil than in any other industry - but today, oil shares have slipped to third place behind utility and chemical stocks. The current value of oil common stocks approaches$43 billion, approximately the same value they had over years ago in May, 1957.In contrast, utility stocks moved from $33 to $50 billion, and chemical stocks moved from $30 to $46 billion over the same period. Over the past 2 1/2 years, oils were one of the major groups showing a decline in their market price, dropping from 20 per cent of the total value Of all common stocks on the New York Stock Exchange to today's figure of approximately 15 per cent of total value.
An investor should not be too alarmed at these statistics because the oil industry has undergone a period of tremendous expansion during its first 100years, an expansion accelerated particularly by the invention of the automobile in the early part of the century. Much of the gain in petroleum demand can be credited to displacement of other fuels. The exact extent of this displacement is not known, but in 1920 oil and gas accounted for slightly less than 18 percent of the total energies used in this country. By 1943 this rate had climbed to 40 per cent, and in 1956 it had reached 67 per cent. Today, oil and natural gas supply 72 per cent of the energy used in the United States.
A consensus of various petroleum economists indicates that oil and natural gas will supply 75 per cent of the energy used in the United States by the year 1967 and that the growth in demand in the U. S. will approximate 4 to 5 percent/year over the next decade. It is estimated that demand will approach 14million B/D by 1967 compared with approximately 9.5 million B/D today; it is further estimated that the Free World oil consumption will increase at an average rate of approximately 7 to 8 per cent/year, nearing 30 million 3/1) in 1967 compared with approximately 17 million B/D today.
The Question of Governmental Oil Import Restrictions
Authors: Peterson William H. 
Published: February 2020

Annual Meeting of the American Institute of Mining, Metallurgical, and Petroleum Engineers, 14–18 February, New York City
How is the Government's oil import control program doing?
In July 1954 Mr. Eisenhower established the Cabinet Committee on Energy Supplies and Resources Policy. On July 29, 1957, the Administration imposed" voluntary", company oil import quotas on American oil importers to maintain "a healthy domestic (oil) production industry" and safeguard" national security." On March 10, 1959 the President by proclamation made the voluntary program mandatory.
But study of the program in practice shows that it is not working out as expected and that there is some doubt that its aims and other related Administration purposes are being achieved.
Take the Administration's anti-inflation policy. To be sure, the President apparently recognized in his March 10th proclamation that in restricting cheap imported oil in favor or more expensive domestic oil he was making the inflation right that much harder, for he called for Government surveillance or domestic oil prices to prevent them from getting out or hand. And indeed while domestic crude oil prices have not risen appreciably during 1959 neither have they fallen appreciably (although there has been some price weakness in the past few weeks).
Domestic prices almost certainly would have gone into a decline if advantage had been taken or much lower-priced Middle Eastern and other foreign crude. Middle Eastern crude's approximate 10 percent price advantage in May, 1958, had widened, if temporarily, to better than 33 1–3 percent in May, 1959.
If anything this price gap is not likely to shrink much and may even increase in the long run; U.S. drilling and development costs generally run a good bit higher than those in the rest or the world, and increasingly so. Why is this? Aside from higher labor costs, probably the main answer lies in the fact that the United States is the scene or the world's highest living standards with the first truly motorized society. So for 100 years this country has been combed for possible oil while its existing economical oil resources have been abundantly utilized and to a significant extent depleted.
So to find oil in the U.S. today as compared to finding it abroad, it is generally necessary to drill to greater depths and with a greater proportion of dry holes or to probe the offshore continental shelf expensive operations which tend to advance the unit cost of domestic oil. Another reason for the cost spread is seen in the figures (1956) for average daily production per well -for the U.S. it is 13 barrels, for Venezuela 176, for Kuwait 5179, and for Saudi Arabia 8650 barrels.
A Method of Projecting U.S. Petroleum Supply
Authors: McGann Paul W. 
Published: February 2020

Annual Meeting of the American Institute of Mining, Metallurgical, and Petroleum Engineers, 14–18 February, New York City
This paper presents a methodology for long-range studies of petroleum supply, to meet protected demands, that involves modifications of procedures used previously. This paper continues a series of papers on this general topic in the AIME, the most elaborate recent one being that by Warren Davis given in February 1958.
The procedures considered here begin with the assumption that the governmental framework of regulations and taxes remains fixed but that price changes. After these procedures have been reviewed, the effects of changing certain governmental controls will be considered in order to judge their potential effects on future supply. This is an essential step because controls cannot be expected to remain static in a situation changing as much as the petroleum industry and because such changed are within the scope of alternative ways of adjusting to impending problems.
The first procedure begins with:trends in drilling success,relation between field income from oil and gas and footage drilled,declines incapacity from production,trends in capacity of new and producing wells,all monetary values are in constant 1958 dollars, andget amounts of domestic crude petroleum production.
From these components protections are obtained of:numbers of future producing wells required,footage drilled,new wells drilled,crude oil found,capacity of producing wells,completion costs,finding costs,production costs, andaverage wellhead crude oil price consistent with the footage-field income relationship.
No attempt is made at this time to explain trends in future production of natural gas or natural gas liquids. Simple protections of these are assumed for the future which are consistent with past trends and forecasts by the American Gas Association. Such forecasts take account of trends toward deeper wells, increasing gas-oil ratios and increasing condensate-oil ratios, but we are not directly concerned with an analysis of gas and condensate in this paper.
Trends in Property Acquisitions and Mergers in the Oil Industry Since 1954
Authors: Farrier H. Marshall 
Published: February 2020

Annual Meeting of the American Institute of Mining, Metallurgical, and Petroleum Engineers, 14–18 February, New York City
In the past few years, the world-petroleum-industry had increasingly felt the-weight of changes in the principal economic factors affecting profits. As a result of theme changes, it has been necessary for many oil companies to acquire certain new facilities in order to strengthen their competitive positions and thereby protect their tremendous investments in crude oil reserves, pipe line facilities, refining operations, and marketing outlets. Principally, these needs have been met by new capital outlays. A supplementary method of acquiring needed facilities, however, has been to obtain existing facilities through complete or partial acquisition oil other companies'properties. It is this method of meeting competitive pressures with which this paper is concerned.
This paper presents a statistical breakdown of the mergers and acquisition which occurred in the oil industry between January 1, 1954, and October 1,1959, showing the frequency with which certain types of properties were acquired in each of the years studied. In addition, it discusses the principal economic conditions which stimulated many of these property transfers, comments on the effects of these mergers on the consuming public, and indicates the types of mergers and the rate at which they may be expected during the next three or four years.
The basic data upon which the statistical analysis presented in this paper is based were taken from several published sources. Obviously they are:somewhat incomplete because not all mergers and acquisitions were reported. However, a careful search was conducted through The Wall Street Journal, The Oil and Gas Journal, Petroleum Week, and The Oil Daily with the result that the data should be reasonably complete and comparable for each of the years studied. It is believed, therefore, that the statistical analysis which follows provides a reasonably accurate indication of the general trend in mergers and acquisitions during the period studied.
Apparent Trends in Mergers
During the period January 1, 1954 to October 1, 1959, there were approximately 519 complete or partial company acquisitions made by 238acquiring companies or individuals, involving solely United States or Canadian properties reported in the trade papers examined. Included in these property transfers were transactions involving common stock mergers, acquisitions of part interests in the common stock of other companies, and purchases of othercompanies' properties. All of the buyers and sellers were engaged in the producing, refining, and/or marketing of crude oil or natural gas liquids either prior to or as a result of these acquisitions.
History Matching Under Geological Constraints Coupled with Multiobjective Optimization To Optimize MWAG Performance: A Case Study in a Giant Onshore Carbonate Reservoir in the Middle East
Authors: AlAmeri Saeeda , AlBreiki Mohamed , Geiger Sebastian 
Published: February 2020

SummaryIn this paper we demonstrate how key geological uncertainties in a giant onshore carbonate reservoir in the Middle East, most notably fracture permeability and saturation distributions, impact the quality of the history match and change the performance forecasts of a planned miscible water alternating gas (MWAG) injection process.Different geological models for the reservoir were designed by integrating static and dynamic data. These data indicated the need to consider fault-related fractures using effective medium theory (EMT) and to update the saturation distribution by integrating special core analysis and log-derived J-functions in the reservoir model during the history matching. Afterward, multiobjective optimization (MOO) was applied for each history-matched model to identify well controls that optimally balanced the need to maximize the time on the plateau rate while adhering to the field's gas production constraints.Our results clearly show that including low-intensity fault-controlled fractures in the reservoir model improved the quality of the history match for the gas/oil ratio (GOR), BHP and water cut (WC). This is especially true for wells located near faults, which were difficult to match in the past. Moreover, our results further show that the updated saturation model improved the quality of the history match for the WC, and honored water saturation from the log with high accuracy, particularly for wells located in the transition zone.Applying MOO for each history-matched model then allowed us to identify well controls for the MWAG injection that could extend the time at which the reservoir would be produced at the plateau rate for up to 11 years and the risk of losing production plateau down to 2 years, while always adhering to the current field operational constraints.We demonstrate how the integration of MOO with an innovative workflow for fracture and saturation modeling impacts the prediction of a planned MWAG injection in a giant onshore carbonate reservoir. Our work clearly illustrates the potential of integrating MOO with new reservoir characterization methods to improve the quantification of uncertainties in reservoir performance predictions in carbonate reservoirs.
Beckman Gas Density Balance
Authors: Johnston Norris , Richards James D. 
Published: February 2020

Fall Meeting of the Southern California Petroleum Section of AIME, 17–18 October, Los Angeles, California

Introduction
Many phases of oil and gas reservoir evaluation, and operation of such properties for maximum economic return, depend on a thorough knowledge of the volumetric behavior of the oil and/or gas contained therein. One of the basic elements in measurements of this sort is the density of the gas phase. This parameter must be accurately known whether the complete Pressure-Volume-Temperature [PVT] study of the oil and gas system is made or whether empirical correlations are being used, as with the method of Marshall B. Standing.
The density of gas may well be used as a monitor on many refinery processes and in an endless list of chemical engineering processes where gas of any composition is an integral part of the process. Some of the gas density-measuring devices on the market now are fairly satisfactory where a large amount of gas is available or monitoring of the density of a large stream of gas is required. Where time is no object or if extreme accuracy is not required, several available instruments prove satisfactory. But where rapid measurements of the density of small quantities of gas are required with a high degree of accuracy, coupled with a minimum of lost motion between samples, the Beckman Density Balance has proved to be invaluable.
The first laboratory model of the Density Balance was installed in Jan., 1955. Except for minor adjustments and one improvement in the interest of corrosion resistance, it has operated for two years on hundreds of samples of gas, giving more precision than is necessary for most PVT work with smaller samples and more quickly than any other method known to the authors. The result are so outstanding that further laboratory development is entirely restricted to other phases of the PVT equipment and procedures.

Principle of Operation
Inside the measuring cell a horizontal quartz fiber supports a light dumbbell-mirror assembly. One ball of the dumbbell is punctured, making it independent of buoyancy effects. The other dumbbell ball rises or dips as the density of the gas fluctuates.
Effect of the Presence of Hydrocarbons on Well Logging Potential
Authors: Kerver J.K. , Prokop C.L. 
Published: February 2020

Fall Meeting of the Southern California Petroleum Section of AIME, 17–18 October, Los Angeles, California

Abstract
Although field observations have indicated that the presence of hydrocarbons in sands may affect the potential recorded on the electric log, no systematic laboratory investigation of the phenomenon has been reported. In the interpretation of the electric log, it is essential that the various factors which influence the magnitude of the potential be known. To fill this need, a laboratory study has been made of the development of the potential in sands containing both brine and oil. The laboratory experiments were conducted on a wide range of porous media, including clean and shaly reservoir rock and pure siliceous material. Potentials were measured over a wide range of oil saturations. It was observed that under specific conditions an oil saturation affected the potential developed across both clean and shaly samples. Slightly shaly reservoir core samples containing high oil saturations developed potentials which made them appear more shaly than they appeared when the cores contained only water. A less pronounced but similar effect was also observed in clean, siliceous materials. The laboratory work suggests that in some cases this phenomenon may have an appreciable effect on the potential recorded on the electric log; in general, however, the effect is probably not serious.

Introduction
Although the potential curve of the electric log has been widely used for a number of years as the basis for lithologic interpretation of strata, it has only been in recent years that the factors responsible for the origin of the potential have been recognized. In their pioneer work on the development of the electric log, the Schlumberger brothers pointed out that the potentials measured opposite sands and shales are different and that the difference is of diagnostic value, but it remained for Mounce and Rust to give a logical explanation of the phenomenon. Mounce and Rust demonstrated that the potential is predominantly electrochemical in nature, and that its existence is dependent upon a salinity difference between interstitial water and the mud or water filling the borehole. They also showed that the seat of the potential is in shale.
Cultural Perceptions of Child Abuse in Terms of Parents Perspective a Qualitative Study in Indonesia
Authors: Dewi Reizkiana Feva Kosmah , Dhamayanti Meita , Rahayuningsih Sri Endah , Mutyara Kuswandewi , Arisanti Nita , Rusmil Viramitha Kusnandi , Sekarwana Nanan 
Published: February 2020

Abstract

Background Child abuse (CA) is a serious problem and difficult to detect. According to World Health Organization (WHO), CA is responsible on 950,000 deaths in children aged below 18 every year. As many cultures as various of CA among parents inside. This research aims to determine the cultural perceptions of child abuse in terms of parents in Indonesia. Method A qualitative study using focus group discussions was conducted to thirty one parents that selected purposively. The discussion centered about CA definition, classification, and frequency, level of CA (mild, moderate, and severe), the difference between violence and discipline. The focus group discussions divided in to 3 groups level education, Elementary/Junior high school, senior high school, and bachelor’s degree. The process offocus group discussion were recorded, transcribed, and analyzed using manifest qualitative content analysis. Results Every cultures in Indonesia perceived that CA is a form of parents’ emotion which lead to injure children physically and mentally. Indonesian cultures were not familiar with neglect and exploitation. Participants’ opinion regarding level of violence can be categorized as severe if leaving wounds, need to be hospitalized, and visumed. The parents assumed as CA if occurred more than twice and/or leaving marks. The discipline’s ussualy purpose is not to mistreat, but for goods, character building, and educating the children. Conclusions Cultural perceptions of parents about CA is a form of parents’ emotion which lead to injure children physically and mentally. The community and health workers should be aware to decrease morbidity and mortality of CA
Neoadjuvant chemotherapy-induced decrease of prognostic nutrition index predicts poor prognosis in patients with breast cancer
Authors: Oba Takaaki , Maeno Kazuma , Takekoshi Daiya , Ono Mayu , Ito Tokiko , Kanai Toshiharu , Ito Ken-ichi 
Published: February 2020

Abstract
Background: The prognostic nutritional index (PNI), which is an easily calculated nutritional index, is significantly associated with patient outcomes in various solid malignancies. This study aimed to evaluate the prognostic impact of PNI changes in patients with breast cancer undergoing neoadjuvant chemotherapy (NAC).Methods: We reviewed patients with breast cancer who underwent NAC and a subsequent surgery for breast cancer between 2005 and 2016. PNI before and after NAC were calculated using the following formula: 10 × serum albumin (g/dl) + 0.005 × total lymphocyte count/mm3. The relationship between PNI and prognosis was retrospectively analyzed. Results: In total, 191 patients were evaluated. There was no significant difference in disease-free survival (DFS) between the pre-NAC PNI high group and the pre-NAC PNI low group (cutoff: 53.1). However, PNI decreased in 181 patients (94.7%) after NAC and the mean PNI also significantly decreased after NAC from 52.6 ± 3.8 pre-NAC to 46.5 ± 4.4 post-NAC (p < 0.01). The mean ΔPNI, which was calculated as pre-NAC PNI minus post-NAC PNI, was 5.4. The high ΔPNI group showed significantly poorer DFS than the low ΔPNI group (cut off: 5.26) (p = 0.015). Moreover, high ΔPNI was an independent risk factor of DFS on multivariate analysis (p = 0.042). Conclusions: High decrease of PNI during NAC predicts poor prognosis. Thus, maintaining the nutritional status during NAC may result in better treatment outcomes in patients with breast cancer.