bluuebunny/crossref_metadata_2025_split huggingface dataset:
Probing Methane Foam Transport in Heterogeneous Porous Media: An Experimental and Numerical Case Study of Permeability-Dependent Rheology and Fluid Diversion at Field Scale
Authors: Zeng Yongchao , Kamarul Bahrim Ridhwan Z. , Groot J. A. W. M. , Vincent-Bonnieu Sebastien , Groenenboom Jeroen , Mohd Shafian Siti Rohaida , Abdul Manap Arif A , Tewari Raj D. , Mohammadian Erfan , Azdarpour Amin , Hamidi Hossein , Biswal Sibani L. 
Published: February 2020

Summary
This paper advances the understanding of foam transport in heterogeneous porous media for enhanced oil recovery (EOR). Specifically, we investigate the dependence of methane foam rheology on the rock permeability at the laboratory scale and then extend the observations to the field scale with foam modeling techniques and reservoir simulation tools.
The oil recovery efficiency of conventional gasflooding, waterflooding, and water-alternating-gas (WAG) processes can be limited by constraints such as bypassing effects (including both viscous fingering and channeling mechanisms) and gravity override. The problem can be more severe if the reservoir is highly fractured or heterogeneously layered in the direction of flow. Foam offers the promise to address the three issues simultaneously by better controlling the mobility of injected fluids. However, limited literature data of foam-flooding experiments were reported using actual reservoir cores at harsh conditions. In this paper, a series of methane (CH4) foam-flooding experiments were conducted in three different actual cores from a proprietary reservoir at an elevated temperature. It is found that foam rheology is significantly correlated with the rock permeability.
To quantify the mobility control offered by foam, we calculated the apparent viscosity on the basis of the measured pressure drop at steady state. Interestingly, the apparent viscosity was found to be selectively higher in the high-permeability cores compared with that in the low-permeability zones. We parameterized our system using a texture-implicit-local-equilibrium model (STARS™ simulator, Computer Modelling Group, Calgary, Alberta, Canada) to illustrate the dependence of foam parameters on rock permeability.
In addition, we created a two-layered model reservoir using an in-house simulator called modular reservoir simulator (MoReS; Shell Research, Rijswijk, The Netherlands) to elucidate the role of different driving forces for fluid diversion at the field level. We took into consideration the combined effect of gravitational, viscous force, and capillary forces in our simulation. We show that the gravitational forces prevent the gas from sweeping the lower part of the reservoir. However, the poor sweep can be ameliorated by intermittent surfactant injection to generate foam. In addition, the capillary force which hinders the gas (nonwetting phase) from entering the low-permeability region can be effectively leveraged to redistribute the fluids in the porous media, resulting in better sweep efficiency. We conclude that foam if properly designed can effectively improve the conformance of the WAG EOR in the presence of reservoir heterogeneity.
An Investigation of the Use of the Spectrograph for Correlation in Limestone Rock
Authors: Jessen F.W. , Miller John C. 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 247–250.

Basic Problem of Correlation
In many areas where carbonate rocks form important parts of the stratigraphic sequence, stratigraphers have experienced varying degrees of difficulty in differentiating and correlating limestone and dolomite units in both surface and subsurface work. With early Paleozoic rocks of the Mid-Continent, insoluble residues yield a remarkable amount of stratigraphic data and relatively good correlations may be carried over broad distances. Unfortunately, neither such information nor electric logs and radioactive logs have been particularly helpful in interpreting the limestone sections of the Permian Basin of West Texas. This is because:the variations in the sections may be very slight;no completely satisfactory method of interpretation has been developed; andthe measurements themselves are not sensitive enough for small variations.
Also, such logs are influenced by the fluid content.
Paleontology and micro-paleontology remain the ultimate arbiters. As a routine tool, however, paleontological examination is slow and tedious. Chemical analysis may be used, but this, too, is extremely slow. Although rocks are not classified according to chemical composition, there is considerable variation with rock types. Correlation by chemical composition has two advantages, first, the characteristics determined are subject to minimum human error and interpretation, and secondly, the lithologic changes are not masked by fluid content as in the case of electric and radioactive logs. Some fossils concentrate certain elementswhich tentatively might be used to date rock units.
Rapid chemical analysis by spectrographic means could be used as an adjunct to other means employed in correlation work, or might, in itself, present a suitable method.
A Study of Electric Log Interpretation Methods in Shaly Formations
Authors: De Witte Leendert 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 103–110.

Abstract
A review is given of the principles on which recently proposed methods of electric log interpretation in shaly sands are based and of the evidence brought up in support of the theoretical derivations. It is pointed out that the qualitative techniques suggested to date have a tendency to be too pessimistic in the prediction of the presence of commercial hydrocarbon accumulation.
In the quantitative treatment, a new concept is introduced, namely that of strongly reduced activity of the double layer counter ions which are present near the negatively charged rock surfaces. This lemma when applied to the calculation of the equilibrium concentrations of interstitial waters yields a set of very simple relations. The resulting expressions for electrochemical potentials across rock samples appear in satisfactory agreement with laboratory experiments. The formulae obtained for the electrical conductivity of shaly formations are of the same form as those arrived at empirically by previous workers. Combination of the expressions for potentials and conductivities gives a direct proof of the Tixier relation which states that for shaly water sands the product of apparent formation water resistivity and apparent formation factor equals the resistivity of the sand 100 per cent saturated with formation water and which was verified by the work of Wyllie and Perkins and their co-workers.
The relations for the resistivities and spontaneous potentials have been extended to the case of hydrocarbon bearing shaly formations, thus laying a formal basis forthe quantitative interpretation of electric logs in shaly oil sands.

Introduction
The presence of disseminated clays in porous rocks saturated with electrolytic solutions has a strong influence on the transference of ions taking place under electrical or chemical potential gradients. Both the electrochemical emf's in evidence on the SP curves of electric logs and the electrical conductivity measured on resistivity logs are directly dependent on the ionic transference in the interstitial waters of the formations traversed by boreholes.
The Encroachment of Injected Fluids Beyond the Normal Well Pattern
Authors: Caudle B.H. , Erickson R.A. , Slobod R.L. 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 79–85.

Abstract
In predicting the sweepout pattern efficiency to be expected in a secondary recovery operation, the reservoir engineer is often confronted with a situation in which part of the producing formation lies between the last row of wells and the reservoir boundary. To date, there has been little or no reference in the literature to sweepout pattern efficiencies in such areas. This paper presents the results of a laboratory study in which the area contacted around the edge of a reservoir injected in a five-spot pattern was determined. The X-ray shadowgraph technique was used in this study.
It was found that surprisingly large portions of the reservoir area lying outside the well network are contacted by the injected fluid before abandonment conditions are reached. In fact, it can be said that at least 90 per cent of the area lying outside the last row of wells and within a distance of one well spacing of these wells will ultimately be contacted by the injected fluid in the case of most water floods. From the results given in this paper, it is possible to estimate not only the extent to which encroachment into these areas will occur but also the injection volume necessary to produce the wells to abandonment conditions.

Introduction
While considerable work has been done in recent years evaluating the fraction of the reservoir contacted as a function of the mobility ratio for several different well patterns, there has been practically no mention of what happens to the oil in that portion of the reservoir which lies between the last row of wells and the reservoir boundary. In fact, the assumption is generally made that little or no recovery can be expected from this area.
Performance of Water Drive Reservoirs, Including Pressure Maintenance, as Determined by the Reservoir Analyzer
Authors: McDowell James M. 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 73–78.

Abstract
A study has been made to determine how the behavior of a water drive reservoir changes as a function of the permeability of the formation and ay a function of the size of the aquifer. The effect of pressure maintenance programs' on the rate of natural water influx is also studied, as well as the influence on the influx of the position of water injection wells with reference to the oil-water contact.
The results are determined by the use of an electrical reservoir analyzer and are plotted as families of curves of pressure, natural water influx, and water injection vs time or cumulative production. Two size aquifers are studied. One is limited with a 36-mile radius, and the other approximates an infinite reservoir. The field remains the same in all respects for the complete study except that the permeability is changed to agree with that assumed for the aquifer.

Introduction
This study was undertaken in order to determine how the pressure decline and water influx of a water drive field would change as a function of the rate of fluid withdrawals, as a function of the permeability of the formation, and as a function of the size of the aquifer. The effect of pressure maintenance programs on the rate of natural water influx was also studied as was the position of water injection wells with reference to the oil-water contact.
The information has been determined by the use of an electrical reservoir analyzer sometimes referred to as a Carter type analyzer. This instrument is an analog type computer which can be set up to represent a water-drive oil field. It can reproduce the past performance of the field in terms of analogous electrical quantities when the proper circuit analog of resistors and condensers has been determined, also, it can determine the future behavior for any method of production which may be selected, or permit the comparison among several different methods.
Corrosion of Oil Well Casing by Earth Currents
Authors: DeWitte Leendert , Radd Fred J. 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 66–72.

Abstract
In many areas casing failures can be directly related to electrical currents observed in the casings. It is the thesis of this paper that the observed casing currents are mainly due to electrochemical potentials of the type in evidence on spontaneous potential curves of electrical logs. The general nature of these potentials are discussed and an equivalent circuit is given for current and potential distributions around open holes. The casing forms a short circuit to these potentials and tends to average the effects of local cells. The case of casing corrosion opposite the Dakota water sands in the salt-mud area of Kansas is discussed and used as a qualitative illustration of the relation between SP's and casing currents. A method of quantitative derivation of casing current distribution from electric log SP curves, using linear transform theory, is described and results are compared with a measured current profile. The effects of hydrogen over-potentials at the cathodic portions of the pipe are considered and some laboratory data are given in support of conclusions regarding the overvoltages.

Introduction
To date an appreciable amount of work has been done on the measurement of oil well casing currents and on the correlation of the anodic portions of the current profiles with corrosive casing failures. Speculations on the origin of the casing currents have, however, remained rather vague; and although almost every plausible cause has been mentioned, there is to the writers' knowledge no clear-cut expose' on the details of the causes of the corrosive currents in the literature.
A study of current surveys and casing failures in the N.W. Burnett field, Ellis County, Kan., indicated the probability that concentration cell emf's between the Wellington salt section and the relatively fresh waters in the Dakota sands were a major cause of the corrosion currents. A more general concept evolved upon analysis of the severe corrosive conditions in the Pleistocene sands in the Ventura Avenue and San Miguelito fields in California.
The Concept "Hydraulic Radius" in Porous Media
Authors: Harmsen G.J. 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 274–277.

Abstract
It is shown that in any isotropic porous medium there is a fixed ratio between the numerical value of the total pore perimeter per unit of cross-section and the specific surface area per unit of bulk volume. The consequences of this fact on the use of the concept "hydraulic radius" in the case of porous media are examined.
The validity for consolidated sands of Kozeny's relationship and of the formula derived by Carman for capillary rise are discussed.

Introduction
In the course of time several quantities and relations have been put forward in order to describe the texture of a porous medium and the flow of fluid through it. Among these relations the so-called Kozeny formula and a formula for capillary rise, for both of which Carman has given a derivation, will be specially considered here. These relations are of a semi-empirical nature and the derivations must be considered to have a heuristic significance only.
Single-Fluid Five-Spot Floods in Dipping Reservoirs
Authors: Prats M. , Strickler W.R. , Matthews C.S. 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 160–174.

Abstract
To gain an insight into the deviations from normal behavior caused by dip, a mathematical study has been made of single-fluid five-spot floods in dipping reservoirs for flooding techniques likely to be employed in such cases. Streamline patterns and sweep efficiencies are computed for a number of different cases, and the results, where possible, are presented in graphical form. An increase in sweep efficiency can be obtained by moving the central injection well updip, and the optimum position is found for several cases. The applicability of the results is discussed.

Introduction
Because of the growing importance of water flooding in California and in other locations where large angles of dip are quite common, it is important to know at least some of the effects of dip on the performance characteristics of water floods in such instances. In the past, only reservoirs having relatively mild dips have been waterflooded. Consequently, little is known today as to the effect of dip on the performance characteristics of a flooding operation from the point of view of field experience; and because of the complexity of the problem, little, if anything, has been done on the problem from the point of view of theory.
There are two distinct aspects of the role played by gravity in a flooding operation. The first is that of the preferential segregation of the reservoir fluids at the time when the flood is to commence. The second is the role that it may play in affecting the performance of the reservoir during the course of the flooding operation. In this paper the reservoir is assumed to be filled with only one fluid, so that there is no preferential segregation of reservoir fluids at the commencement of the flood. Moreover, the injected and in-place fluids are assumed to have the same characteristics, so that in effect we consider only a single-fluid problem.
Material Balances in Expansion Type Reservoirs Above Bubble Point
Authors: Hawkins Murray F. 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 267–271.

Introduction
One problem of reservoir engineering is the early estimation of the size of newly discovered reservoirs. Often these reservoirs are the expansion type in which sizeable pressure drops occur incident to the production of small fractions of the oil reserve, above the bubble point, and a material balance equation may be solved to find the reserve.
The early form of this equation considered only the compressibility of the oil. Later Hall showed that the compressible nature of the formation rock is a significant factor in production above the bubble point, and he presented a new equation which includes a formation (rock) compressibility term.
This note presents a further extension of the material balance equation as applied to volumetric, unsaturated reservoirs above the bubble point by including a term for the presence and compressible nature of the interstitial water.
A Practical Method for Treating Oilfield Interference in Water-Drive Reservoirs
Authors: Mortada Mohamed 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 217–226.

Abstract
A practical analytical method is developed in this paper which provides the practicing reservoir engineer with a handy method for analyzing oilfield interference problems. The procedure employed entails the principle of superposition of individual effects. A set of charts has been developed and can be used to evaluate the individual effects. The charts represent non-steady state pressure distribution in an extensive aquifer due to a constant rate of production from an oilfield which can be approximated by circular geometry; they are constructed from solutions to the diffusivity equation considering a circular sink as distinguished from a point sink. The solutions are obtained partially from mathematical considerations and partially from analog and digital computations.
By virtue of the method of images, the charts can be used also to treat the case of production near a fault. In addition, provisions are made for treating oil fields, which are produced by partial water-drive.
Treating an actual field case is deferred to a subsequent writing; however, illustrative example is presented to demonstrate the method of application.
The pressure distribution in linear and limited radial aquifers is currently under study.

Introduction
With the increasing difficulty of discovering new oil reserves, attention is necessarily focused on the efficient development and production of existing reservoirs. Efficient production depends on the availability of reliable means for predicting the pressure-production behavior of oil fields. The prediction is usually performed by analytical methods or computers. Analytical methods are often limited to systems which can be approximated by simple geometry. However, analytical methods have the distinct advantage of being readily performed without special equipment. Analog and digital computers lend themselves to a variety of problems, but are not always locally available and consequently their use is limited.
Calculation of Unsteady-State Gas Flow Within a Square Drainage Area
Authors: Douglas Jim , Peaceman D.W. , Rachford H.H. 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 190–195.

Abstract
The problem of unsteady-state gas flow through porous media has been solved numerically only for the case of linear or radially symmetric reservoirs. A recently introduced numerical method for solving the unsteady-state heat flow equation in two dimensions is applied to the calculation of the depletion of a square region containing a perfect gas. Solutions are presented in graphical form for various values of dimensionless parameters. The solutions are compared with published solutions for radial reservoirs.

Introduction
The problem of unsteady-state flow of gas through porous media gives rise to a second-order non-linear partial differential equation for which no analytical solution has been found. Numerical approximations to solutions of the gas flow problem have been obtained by the stepwise solution of an associated difference equation. However, the methods so far developed have required that the reservoir be either linear or radially symmetric. This restriction in shape has been necessary so that only two independent variables be considered, namely, one distance variable and time. In order to deal with reservoirs having more realistic shapes, it is necessary to develop numerical procedures for the solution of the gas flow problem involving two distance variables.
A numerical procedure, denoted as the alternating-direction implicit method, for the solution of the heat-flow problem in two dimensions has recently been introduced. By the use of this procedure, approximate solutions have been obtained for heat-flow problems in a square, and in regions having various non-rectangular boundaries. Because of the similarity between the equation for heat conduction in solids and the equation for gas flow in porous media, it is reasonable to expect that the alternating-direction implicit method should also be useful for solving the gas flow problem in various two-dimensional regions.
Locating Casing Shoe Leaks With Radioactive Argon
Authors: Kohl J. , Newacheck R.L. , Anderson E.E. 
Published: February 2020

Published in Petroleum Transactions, AIME, Volume 204, 1955, pages 213–216.

Abstract
Radioactive materials were used underground before the advent of the nuclear reactor. Radium containing ores have been mixed with cements and other materials for later location in oil wells by gamma ray logging since 1940. Perforating bullets have been marked with radium salts, and radioactive materials have been added to drilling muds to find the cause of "lost circulation." More recently colloidal suspensions of radioactive cobalt-60 and silver-110 and solutions of I-131 have been used in waterflooding operations to determine injection profiles, flow paths and water velocities.
In this paper a recent and interesting underground tracer application is discussed. Development work and field engineering were carried out under the direction of Tracerlab, Inc., with assistance from personnel of the client. A gaseous tracer, argon-41, was used in an attempt to determine the cause of leakage from an underground gas storage reservoir.

Statement of Problem
This gaseous tracer application was carried out for the Natural Gas Storage Co. of Illinois. This company has developed an underground gas storage field 1,750 ft below the surface of the earth near the village of Herscher, Ill., about 60 miles south of Chicago. The total volume of gas stored in the field was estimated to be about 13 billion cu ft in the spring of 1954. The field has a maximum estimated storage capacity of 90 billion cu ft. The gas is contained in the Galesville sandstone, previously a water bearing formation of about 25 per cent porosity. The water as it is pushed out by the gas forms a barrier for the gas around the edge of the reservoir. Over the top and beneath the bottom of the reservoir are located several layers of impervious rock, which barring cracks or unplugged and unknown wells should act as seals.