bluuebunny/crossref_metadata_2025_split huggingface dataset:
Fundamental Study of Imbibition in Fissured Oil Fields
Authors: Iffly R. , Rousselet D.C. , Vermeulen J.L. 
Published: December 2007

Abstract
Waterflood efficiency of a fissured oil is closely dependent on the volume and speed of water imbibition in the elementary blocks.
A large number of laboratory tests have been performed on fluids and porous media taken from a performed on fluids and porous media taken from a field exploited by ELF, and have helped to ascertain the effect of the block height and permeability, and the conditions at their limits as well permeability, and the conditions at their limits as well (some figures may contain water or oil or may be tight), on oil recovery.
The results show how important are the physico-chemical bondings between connate water, physico-chemical bondings between connate water, injected brine, oil and rock at any time during imbibition: minor differences in lithology may consideration alter the recovery laws. Similarly, some organic molecules in the fluids influence oil recovery much more than one might expect according to the variations of cos alone. As one does not know how to represent these physico-chemical bondings, it is not permitted to perform laboratory experiments with fluids an/or core different from the real one (except for special cases).
Laboratory measurements, together with numerical simulations, have even results which allow to understand the role played by gravity, capillarity, boundary conditions, and end effects an the imbibition.

Introduction
The development of one of our off shore oil fields which is composed of alternating silt and fissured limestone layers has enabled us to make a detailed study of the effects of imbibition when the field is flooded with sea-water. Since the silt layers contain most of the oil and the limestone layers are continuous and largely fissured, it was possible to represent the situation by the following possible to represent the situation by the following elementary structural model (figure 1-a): a homogeneous matrice containing primarily oil and interstitial water, which is bordered on the top and bottom by two horizontal and parallel fissured Plans, which carry the intrusive water and drain Plans, which carry the intrusive water and drain off the oil displaced from the matrice by imbibition.
This model can be itself reduced to the experimental schema (figure 1-b),: a porous medium sample set up vertically and containing initially oil and water at irreductible saturation. Water is brought in contact with the top and bottom of the sample and its hydraulic potential is kept constant by means of a lateral by-pass. The displaced oil is collected selectively in two graduate tubes as shown in the figure 1-b. Such is the elementary schema considered in the present study.
Gasification and Hydrosulfurization Becoming Important Tools
Authors: Bertetti J.W. 
Published: December 2007

This paper was prepared for the 47th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in San, Antonio, Tex., Oct. 8–11, 1972 Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor of the appropriate journal, provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers Office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
The concurrent problems of limited natural gas supply and the rapidly increasing demand for low sulfur fuel oils has spurred significant activity in many research organizations and in engineering-contracting companies.
New tools for the petroleum refining engineer have been provided by several licensors of proprietary catalysts and technology for converting naphtha to substitute natural gas, and several similarly providing for desulfurization of providing for desulfurization of petroleum stocks including heavy petroleum stocks including heavy residual fuel high in sulphur and in metals.
There are two new problems of special interest facing petroleum refining engineers. one is related to the fact that much of the fossil fuel consumed in the world contains so much sulfur that its combustion causes objectionable contamination of the atmosphere. The second arises from the fact that this country's major clean fuel, natural gas, is suddenly realized to be in short supply. The refinery engineer, thanks to the efforts of many research organizations, has the tools to desulfurize fuel oils and to convert oil stocks to substitute natural gas.
With respect to atmospheric pollution, it has been noted that most of the sulfur oxides in the air in industrial and congested areas is the result of combustion of coal and fuel oil, with each on the average contributing about one-half. Many of those who consume coal and oil fuels are under considerable pressure to reduce the emission of sulfur oxides.
Engineered Hcl-HF Treatments Provide Successful Stimulation in Cook Inlet
Authors: Wieland D.R. , Vinson M.E. 
Published: December 2007

Abstract
Successful stimulation of offshore wells in Cook Inlet, Alaska, has been accomplished using HF-HCl acid mixtures in carefully engineered treatments. Many stimulation techniques, including HF-HCl mixtures, have been tried previously but none have been effective. Due to the high solubilities of the producing formation, the Hemlock, in hydrofluoric acid, it was felt that HF-HCl mixtures could provide successful stimulation. The problem was approached from an engineering viewpoint with the aid of Acid Response Curves of the Hemlock. A treatment was designed which consisted of the following steps:Solvent preflush to cover the possibility of asphaltine or paraffin protective coating on the rock.A 2.5% HCl preflush to remove calcareous materials.A 12% HF-10% HCl stimulation stage using a mutual solvent.A 2.5% HCl overflush to maintain low pH and achieve penetration.
Due to the formation thickness a staged treatment was used, with each stage consisting of the above steps. With only slight variation in some materials, the same treatment was used on producers and on injection wells.
Production was more than doubled in producing wells with no appreciable decline after eight months. The injectors were increased by more than 500 percent and the injection profiles were extremely improved.
The purpose of this paper is to present the factors involved in design of treatments for the Hemlock in Cook Inlet, and show how these factors were used to arrive at successful stimulation treatments. A comparison of results with those of previously used treatments is presented.
Vertical Permeability Measurements Swan Hills Reef Complex
Authors: Gutek A.M.H. , Clark K.K. 
Published: December 2007

This paper was prepared for the 47th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in San, Antonio, Tex., Oct. 8–11, 1972 Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor of the appropriate journal, provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers Office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
To obtain accurate data for use in calculating vertical fluid flow within a reservoir, in situ measurements of vertical permeability were conducted on five wells in the South Swan Hills Unit. These measurements quantified the permeability parameters for subsequent model permeability parameters for subsequent model studies of the Light Brown member of the Beaverhill Lake formation.
This paper presents a description of the data collection technique employed and the results for the vertical permeability measurements.
Included in the discussion is a treatment of the data analysis for a single measurement utilizing:the two techniques presently available in literature and a variable rate pressure matching procedure.
Based on pressure matching procedure. Based on the data obtained and the results of the testing as discussed in this paper, it can be concluded that a viable technique is available for measuring vertical permeability. Additional refinements in permeability. Additional refinements in the field operations associated with this type of pressure testings,, can be made, but overall a success ratio of 100% should not be expected.
The successful application of this type of measurement to relating core analysis data to the needs of an adequate reservoir description should be of interest to any performance study.

Introduction
Every reservoir engineer has probably recognized that the single, most probably recognized that the single, most important contributing factor to a useful simulation is the description of the reservoir being studied. The reservoir description must include permeability values which, will govern the fluid flow within the model. These-data are generally obtained from core analysis and may be tailored to reflect information available from pressure transient testing of producing or injection wells. In the case producing or injection wells. In the case of three dimensional or two dimensional cross sectional studies the vertical as well as the horizontal permeability must be quantified.
Drillstem Test Analysis Utilizing McKinley System of Afterflow Dominated Pressure Buildup
Authors: Milner E.E. , Warren D.A. 
Published: December 2007

This paper was prepared for the 47th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in San, Antonio, Tex., Oct. 8–11, 1972 Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor of the appropriate journal, provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers Office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
In a wildcat well or early in the life of a reservoir, drill stem test data is quite often the only means available to estimate reservoir values of transmissibility, effective permeability, well bore damage, well bore permeability, well bore damage, well bore stimulation and productivity.
The Horner pressure buildup method is generally accepted as the best means of determining reservoir data from short time tests such as a drill stem test.
The Horner method requires that the steady state or straight line portion of the buildup curve be reached. For various reasons, approximately 25% of all drill stem tests run do not meet this requirement. This group of wells are the ones with the highest economic risk involved in making a decision on whether to abandon or complete.
A 1971 paper published by Mr. McKinley, "Transmissibility from Afterflow Dominated Pressure Buildup Data", gives a means to Pressure Buildup Data", gives a means to calculate reservoir values when pressure buildup curves are still under the influence of afterflow.
A research program was recently completed using drill stern test data to calculate transmissibility and effective permeability by the McKinley method and to compare the results obtained against the Horner method.
Fifty drill stem tests were chosen for analysis that had an appreciable afterflow period and steady state period on the same buildup curve. The comparison of results was very close as long as the basic assumptions were not deviated from too far. Most drill stem tests, where it is necessary to use the afterflow buildup method, do deviate considerably from these basic assumptions.
Therefore, it is necessary to use a correction factor in interpreting the afterflow method.
A New, Surface Recording, Down-Hole Pressure Gauge
Authors: Miller G.B. , Seeds R.W.S. , Shira H.W. 
Published: December 2007

This paper was prepared for the 47th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in San, Antonio, Tex., Oct. 8–11, 1972 Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor of the appropriate journal, provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers Office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
A new, electronic, surface recording, down-hole pressure gauge utilizing a quartz transducer is described. pressure gauge utilizing a quartz transducer is described. Features of the gouge include wide range (0–12,000 psi), high resolution (0.01 psi), no hysteresis and high stability.
Operational principles of the gauge are described in general. Measurement techniques based on field experience are outlined. Field, Laboratory and calibration data are presented to illustrate the performance of the gouge.

Introduction
An extremely sensitive, high dynamic range, electronic pressure gauge has been developed. The specific pressure gauge has been developed. The specific configuration described herein has been designed for bottomhole placement in oil wells. Measurements are displayed and may be recorded on the ground surface.
The measurement range is from zero to 12 Kpsi and the resolution is better than 10 mpsi throughout the entire operating range. Accuracy is 0.025% of reading for pressures greater than one Kpsi. The precision is better than 150 mpsi throughout the precision is better than 150 mpsi throughout the entire range.
In addition to the surface recording capabilities of the instrument, other advantages include (1) the inherent ruggedness of the transducer, (2) high stability of calibration (good for at least one year), (3) simple operation, (4) low power consumption (16 watts total, 140 milliwatts down-hole) and (5) no observable hystersis. The down-hole sonde will operate continuously at ambient temperatures up to 150 deg. C (302 deg. F). The sonde case is constructed of 17-4-PH stainless steel.
Estimated Effect of Horizontal Fractures on Production Capacity
Authors: Crawford Paul B. , Landrum Bobby L. 
Published: December 2007

Abstract
An electrical model study has been made of the effect of horizontal fractures on the production capacity of fractured wells. For thin reservoirs it is shown that increases in production capacity by factors of 4 to 12 may be obtained if the radius of the fracture is between 0.2 and 0.6 the drainage radius. For thick reservoirs the increases in production capacity may be near 1.4 to 3.8 if the fractures are between the same radii as indicated above. For thin reservoirs there appears to be little difference in production capacity whether the fracture is located at the top, bottom or center of the pay. However, for thick reservoirs and long fractures the center of the pay is indicated to be more responsive than other locations. One large pancake fracture is shown to be more effective for increasing the production capacity than three fractures with one-third the radius. A single horizontal fracture whose radius is 0.6 the drainage radius may result in an increase in production capacity by a factor near 6. Three fractures whose radius is near 0.2 the drainage radius are indicated to result in an increase in production by a factor near 3.5. Inclined circular fractures are indicated to be slightly less effective than horizontal fractures of the same radius. Elliptical fractures produce approximately the same effect on the production capacity as circular horizontal fractures with the same radius as the average radius of the ellipse.

Introduction
Commercial reservoir fracturing techniques are believed to result in the creation of vertical, horizontal and perhaps inclined fractures, depending on the nature of the formation fractured and the fracturing process applied. The creation of fractures normally results in an increase in the production capacity of the well. Qualitatively, the production capacity is believed to increase as the size of the fracture increases.
A New Inhibitor for Corrosion In Aerated Sour Waters
Authors: Annand R.R. , Martin R.L. 
Published: December 2007

Abstract
Aggravated corrosion conditions caused by FeS sol ids and by mixed air plus H2S interactions are responsible for some of the highest equipment failure rates in the petroleum industry. laboratory studies have shown the existence of a transient, ionic, sulfur species which is formed when air and H2S react in an aqueous environment. Iron sulfide catalyzes the reaction to form the species and perhaps also its decay. In addition, the dispersed FeS particles cause an aggravation of the corrosion independent of its catalytic effect on the air/H2S reaction. Furthermore, deposits of FeS cause under-deposit corrosion when air is mixed with sour fluids. A new organic sulfo-phosphate composition has been found which effectively inhibits the most severe combinations of these conditions. It also inhibits cracking in H2S environments.

INTRODUCTION
Even after a considerable number of years of experience in this laboratory working on inhibition of H2S-caused corrosion in petroleum equipment, there remain a significant number of puzzling questions about the corrosion effects observed in the field. The work reported here covers experiments designed to try to elucidate the features of some of these puzzling occurrences and identify at least some of the causes. In addition, we have developed a corrosion inhibitor which is quite different from the conventional kind and is much more effective under the conditions described. Specifically, we have found that oxygen and iron sulfide solids are significant contributors to the corrosion process such that rates as high as several hundred MPY (mils penetration per year) have been observed both in the field and in the laboratory.
A New Sand Control System
Authors: Mann R.L. , Phansalkar A.K. , Landers J.E. 
Published: December 2007

Publication Rights Reserved
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and considered for publication in one of the two SPE magazines with the paper.

Abstract
A new system for controlling the problem of sand production in oil and gas wells has been developed and evaluated. This new technique involves placement of a permeable barrier between the formation and the producing wellbore. Slurry is mixed on the surface and then pumped into the well using standard cementing techniques. The permeability of the set material is as high as 5 darcys. Laboratory data, including pumpability, setting temperatures, permeabilities obtained, strength level obtained, etc., are presented. Development of permeability is an inherent characteristic of the slurry, and the system can be tailored for use under virtually all existing well conditions. Results to date indicate that this system should have wide application in the general field of sand control.

Introduction
The production of sand with oil and gas has long been a serious problem in the oil industry. It greatly complicates and in some cases prevents the production of oil and gas from unconsolidated formations. The influx of sand into the wellbore raises the economic limit on wells for various reasons which are listed below:The replacement or repair of lines, chokes, valves, and meters due to erosion by the flowing sand.Workovers due to the sanding out of wells.Loss of wells due to casing or liners collapsing.Removal of sand and silt from the produced crude.Lowering production rates to decrease sand cuts.Cleaning out of surface facilities.Extra expense of downhole sand control devices, etc.
Significance of Shale Gas as an Indicator of Abnormal Pressures
Authors: Fertl Walter H. 
Published: December 2007

Abstract
Drilling-mud logging through the years has primarily been a tool of the explorationist for formation evaluation. However, continuous well-site analysis of the mud and cutting returns has also become an important tool in drilling control.
The amount of the gas content in the mud system while drilling shales can be indicative of abnormal formation pressures. However, experience indicates that depending on the geological environment and the drilling technique applied such mud logging methods may or may not be directly related to downhole, in-situ pressure profiles.

Introduction
Modern drilling technology is based on three main concepts, namely: well planning, well control, and optimization of drilling operations.
Often there is only a fine line between minimum over-balance of the drilling mud and the possibility of a well kick. This in turn makes well control a must, and the ability to immediately recognize and evaluate abnormal, downhole pressure conditions is critical. Many pressure detection methods are available or have been proposed and numerous technical papers have been written on the subject.
The best approach for identification and evaluation still is the study of a combination of several surface measured parameters verified by the interpretation of open hole logging data.
The amount of the gas content in the mud system while drilling shales can be indicative of abnormal formation pressures. However, since the gas cut can be a function of the geological environment penetrated, the drilling technique applied, and the downhole penetrated, the drilling technique applied, and the downhole thermodynamic conditions prevailing, this gas parameter may not have any direct relation to in-situ pressure profiles.