bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Effect of Pattern Confinement On Oil Recovery For the Five-Spot Pattern
Authors: Dranchuk P.M. , Jain A. 
Published: March 2010

Abstract
Pilot water floods are commonly conducted in order to evaluate the advisability of embarking on a full-fledged waterflood program. However, it has been known for some time that, as a result of oversweep, recoveries from such pilots tend to be over-optimistic. Consequently, the uncertainty in field recovery predictions based on pilot performance may be quite large.
In order to examine the oversweep phenomenon, a laboratory study was conducted on an isolated five-spot and a partially confined five-spot pattern. It was observed that in the former oil recovery increased steadily until field boundary interference was encountered, whereas in the latter it levelled off at a value of 155 per cent of the oil contained within the pattern. From this it was concluded that confined behaviour cannot be expected of an isolated pattern and that a simple pattern cluster may be used to limit the amount of oversweep.

INTRODUCTION
THE IDEA OF CONDUCTING A PILOT FIELD TEST before proceeding with a fully developed waterflood is almost as old as waterflooding itself. Although the wisdom of conducting pilot floods has seldom been questioned, the ideas concerning the manner in, which the test results should be used have undergone gradual change.
Initially, it was believed that observations made on a pilot represented those which would have been observed had the pilot area been examined during a fully developed flood. The realization that this belief was not generally valid led to a variety of laboratory investigations in order to determine what actually occurred during a pilot flood. During the course of such laboratory studies, it was observed that in a fully developed flood the patterns employed behaved as if they were confined, whereas in a pilot they behaved as if they were unconfined or partially confined. That is, it was observed that in a pilot the movement of the injected fluid is not confined to the area enclosed by the pilot perimeter(1)–(11).
On the basis of these observations and as part of a continuing study in this area, it was decided to examine the effect of various degrees of confinement on oil recovery. Although the authors were familiar with the work of Craig(12) and Bernard and Caudle(l3), they chose to examine the simpler but more cumbersome unconsolidated finite system

EQUIPMENT
The model studied consisted of a 1/4-inch-thick pack of US 30–40 industrial glass beads, confined between two 50-inch-diameter, 2-inch-thick lucite plates which were separated by a lucite washer that measured ¼ inch thick, 50 inches OD and 46 inches I.D. Wells were simulated by means of 1/8-inch-diameter brass tubes which passed through the bead pack and both lucite sheets. Each of these tubes contained four 1/32-inch perforations in the bead pack interval and was fastened in such a manner as to prevent bulging of the lucite sheets when the model was pressured. The model contained a total of 185 wells, drilled on 4-inch centers.
A Reduced Equation of State Applied to Generalized Compressibility Factor Tablest
Authors: Purvis R.A. , Robinson D.B. , Dranchuk P.M. 
Published: March 2010

Abstract
This paper reviews the general problem of finding an equation of state for a pure substance, and discusses the various ways of analyzing the isochores. The approach used was to replace the conventional isometric diagram showing the vapour pressure curve with either a ZT, versus Tr isometric diagram or a P r/Z versus Pr isometric diagram. The latter diagrams show the two-phase envelope which permits use of the saturated state for the origin of individual isochors. This results in the density implicit formulations.
(Equation Available In Full Paper)
which may be conveniently solved with a digital computer.
To demonstrate the method, analytical expressions were developed to represent the compressibility factor tables of Lydersen et a1. For reduced densities greater than one, in the reduced temperature range from 0.3 to 3.0, and the pressure range from saturation to Pr = 30, a standard relative error of 0.65 per cent was obtained with only five constants. The approach is also applicable for reduced densities of less than one, but, at the present time, owing to an inability to 6accurately describe the saturated vapour curve in terms of density, the results are only qualitatively Correct. The sparsity of data for Ze values of 0.25 and 0.29 in this region prevented development of a cross-correlation with Z.

INTRODUCTION
COMPUTER PROGRAMS used for modelling the performance of petroleum reservoirs, or for describing chemical other industrial processes, frequently require a method for calculating fluid densities. This is usually accomplished through the use of a suitable equation of state or through corresponding states correlations, The latter are often used to estimate the density of pure substances, and they can be extended to mixture through the use of the concept of pseudocritical properties.
In order to use corresponding states correlations, a suitable method must be found to adapt the information to computer use. This may be accomplished by applying interpolation techniques to tabular data which have been read into memory, by fitting empirical functions to all or part of the data or by using the reduced form of an equation of state. Of these three possibilities, the use of interpolation techniques is considered to be the least desirable, because large-scale data storage and subsequent retrieval is an inefficient computer operation. The well-known equations of Beattie and Bridgeman(14), and Benedict, Webb and Rubin(15) have been applied in reduced form to generalized correlations by Su and Viswanath(18)
Good accuracy has been achieved using these equations in the gaseous region, but unfortunately it has not been possible to find a single set of coefficients that will give satisfactory results over the entire liquid, gaseous and saturated regions. Hirschfolder, Buehler, McGee and Sutton(7) have developed a generalized equation of state in which different functions are used for the three regions defined as:gas, where the reduced density is less than one;
Drillirng the World's Most Northern Wildcat
Authors: Hood G.L. 
Published: March 2010

Abstract
Planning of the first well to be drilled on Ellesmere Island began in 1969, with the first shipload of expendible drilling supplies arriving on the Fosheim Peninsula in August. Rig selection took place in the spring of 1970 and a helicopter-transportable rig was chosen, due to the rugged mounta.nous terrain on Ellesmere and Axel Heiberg islands. The rig camp, fuel and additional drilling supplies were brought in by ship in August of 1970. The main rig components were assembled in Edmonton and flown to the Fosheim N-27 location in February 1971. The transportation of the fuel and supplies from the beach to the drilling site was carried out primarily by tracked vehicle.
The well was spudded on March 25, 1971, and reached a total depth of. 14.022 feet on December 18, 267 days from spud. Very hard drilling was encountered throughout the entire hole and at total depth 136 bits had been used, including 23 diamond bits. A 13 3/8 -in casing failure forced the setting of 9%-in- casing much shallower than originally programmed and ultimately led to a string of 7-in. casing being set. During the drilling of the well a number of specialized drilling materials, tools and equipment were used.

Introduction
PANARTIC FOSHEIM N-27 was drilled on lands originally formed in from Great Plains Oil & Gas Ltd. et al. The well was drilled by Panarctic Oils Ltd. in partnership with Deminex (Canada) Ltd.
Due to the remoteness of the Ellesmere bland loeation, the high cost of transportation of men, equipment and supplies was the primary consideration in planning the world's most northerly wildcat. As a result of the nature of the Fosheim structure, with 8,000 feet of closure, special precautions were taken against the possibility of encountering abnormally pressured formations. An extra unprogrammed casing string at 12,000 feet made it necessary to drill 6-inch hole for the last 2,000 feel, which greatly reduced the penetration rate and considerably increased well cost.

GEOGRAPHIC LOCATION
Ellesmere is the most northerly of Canada1s Arctic Islands. The drilling site itself is 700 miles from the north pole, 1,400 miles northeast of Yellowknife, more than 2,200 miles from Calgary and 2,600 miles due north of Toronto, as shown on Figure 1. Geographically lhe location, situated atop a 2,000-foot mountain of permanently frozen rock, presented the most difficult access problem of any well yet drilled in the Arctic Islands. In summer months the view from the rig- overlooking the blue open water of Eureka Sound with the 8,000-foot ice-capped peaks of Axel Heiberg Island in the background would rival a spring scene in the Canadian Rockies.

GEOLOGY
The Fosheim anticline is one of the largest known surface structures in the Arctic Islands. The structure lies within the Sverdrup basin, being close to the eastern margin. This large feature is approximately 16 miles long and 8 miles wide covering a total of 25,000 acres.
The Fosheim anticline is a "box" fold, based on the increase of surface dips from the crest to the flanks of the structure.
The Influence of Natural Convection In Gas, Oil And Water Reservoirs
Authors: Aziz K. , Bories S.A. , Combarnous M.A. 
Published: March 2010

Abstract
Natural convection in a fluid layer is a phenomenon which has been the topic of numerous studies. A similar phenomenon has been observed in porous media. In the first part of this paper we review some recent theoretical and experimental studies which allow a better understanding of some quantitative aspects of natural convection in porous media. This review is confined to the case in which compressibility effects are negligible as compared to thermal expansion effects and where the porous layer is homogeneous. Some results are presented on natural convection in a horizontal layer with different types of boundary conditions and in a sloped layer bounded by isothermal planes. Some aspects of mixed convection are also discussed.
The second part of the paper is concerned with practical cases. As a major example we give the description of natural convection occurring in the Lacq gas reservoir. We also present some examples of oil production operations where thermal connection may have an influence. These may be classified into two categories:convective motions already existing in a reservoir and having an influence on the handling of the recovery methods;convective motion induced by the recovery technique itself (thermal methods).
Finally we discuss the case of thermal convection in aquifers, with special reference to the understanding of geothermal areas.

INTRODUCTION
NATURAL (or free) thermal convection in a fluid layer is a physical phenomenon which' has been the topic of numerous studies(l, 6, 11, 28). When in a fluid phase the vertical component of the temperature gradient has the same direction as gravity, the upper layer of the fluid is heavier than the lower and some motions, called convection motions, may exist. These motions tend to reduce the adverse density gradient.
The existence of convective motions in areas of geothermal activity has been known for a long time. The existence of the solid matrix of the porous medium does not modify in any important manner the qualitative aspects of the phenomenon. This analogy between the fluid layer and the porous medium has been justified by a number of recent studies which have also provided considerable quantitative information (7, 12, 19. 22, 24. 26). These studies pertain to the ease in which compressibility effects are negligible as compared to the thermal expansion effect and where the porous layer is homogeneous and bounded by parallel planes.
The problems considered in this paper areconvection in horizontal layers,convection in sloped Jayers andmixed (forced and free) convection.
It is possible to gain a good understanding of the phenomenon for almost all practical cases; however, the direct application of the results to practical problems in a quantitative manner is not always easy. This difficulty is due to the complexity of real boundary conditions, the nonuniformity of a real porous structure and also, in some cases, the influence of compressibility effects.
Enhanced Recovery Trends In Alberta
Authors: Strom N.A. , Bray J.A. , Berndtsson N.G. 
Published: March 2010

Abstract
Application of fluid injection schemes for the purpose of enhancing recovery from oil pools in Alberta has grown from very modest levels in the early 1950s to a current position in which about one-third of the original recoverable conventional oil reserves of the Province are attributed to enhanced recovery schemes. The growth of fluid injection operations bears a rather close relationship to the history of development of the major geological plays in the Province over the twenty-year period. The types of schemes implemented and the recovery improvements generated have been governed by prevalent technology, and other factors such as well spacing practices unitization and levels of market demand. The slackened rate of finding new oil pools combined with the burgeoning demand for crude oil should lead to more attractive price/cost relationships, which in turn should generate new technologic innovations in reservoir displacement and well operating mechanics. Future trends in enhanced recovery operations may be forecast by a consideration of the amounts of oil not recovered by present depletion methods and the risks and potential benefits of emerging enhanced recovery techniques.

Introduction
IS ESTIMATED that by the end of 1972, some 33 billion barrels of crude oil initially in place had been discovered and developed in some 1400 separate pools within the Province of Alberta. These pools cover a combined area of nearly 3000 square miles and are drained by some 14,000 producing wells. Of the total oil in place, about 33 per cent or 11 billion barrels is believed recoverable by the mechanisms currently being applied.
Particularly in the past fifteen years, concerted efforts have been taken to improve the recovery from oil pools in Alberta. As a result, some 3.7 billion barrels of crude oil, or approximately one-third of the total original recoverable reserves, are now directly attributed to the application of enhanced recovery techniques. The more significant of these schemes are distributed across the Province roughly as shown in Figure 1. Today there are about 350 enhanced recovery schemes operating in the Province, containing a total of 2600 injection wells with a combined daily injection of 1.6 million barrels of water, 136 million cubic feet (3) Solvent Floods – horizontal, vertical.
At the end of 1972, the reserves attributed to the major recovery mechanisms being applied in Alberta oil pools were divided in the manner shown in Table 2. Based on these statistics, the following observations can be made:
water flooding- accounts for nearly 90 per cent of the additional oil recoverable by fluid injection schemes; gas flooding has been negligible; vertical flooding is much more efficient than horizontal flooding; vertical solvent flooding, with an over-all recovery factor of 85 per cent, is the most efficient displacement process being applied. Although the over-all gain in recoverable reserves of some 3.7 billion barrels is respectable, the challenge of the next decade here in Alberta may be expressed this way:
A System For Offshore Drilling In the Arctic Islands
Authors: Baudais D.J. , Masterson D.M. , Watts J.S. 
Published: March 2010

Abstract
This paper describes the ‘method used to drill an expendable delineation well from an ice platform 8 miles offshore in the Hecla and Gripe? Bay of the Arctic Ocean. Planning pf the Panarclic Tonn etal CS W Hecla N-52 well began in early 1978. However, a considerable amount of horizontal ice movement data had been collected in 1971 and 1972 in several areas of the Arctic Islands to determine the feasibility of drilling from the ice in the latter months of the’ Winter.(1)
The design and construction of the ice platform, the drilling 1'ig selected for the project, the subsea equipment used and the sequence of operations which were followed to drill the Hecla N-52 well are presented in the paper Flooding of the ice platform began on November 28, 1973 and was completed on February 3, 1974. The Hecla, N-52 well was spudded on March 6 and the rig was released on April 15, 1974. Performance of the ice platform and the special subsea equipment used during the drilling period is reviewed.
Operating experience gathered from the Hecla N-52 well demonstrates that drilling an offshore well in. certain areas of the Arctic Ocean from the ice is feasible.

Introduction
IN ITS OPERATIONS OVER the past five years, Panarctic Oils Ltd. has used heavy aircraft on ocean ice airstrips and moved heavy loads by truck across the ocean ice between islands, recognizing that the thick. ocean ice is capable of being used to advantage in the late winter months. Ice strength calculations indicated that it should be possible to drill offshore wells using the ocean ice as a platform for a conventional landtype rig.
The feasibility of drilling offshore with a slim-hole land rig was demonstrated in the spring of 1973 when a small 150-ton Gardner-Denver 2000 drilling rig was used to drill four stratigraphic tests ranging in depth from 833 to 1700 feet in Kristoffer Bay near Ellef Ringnes Island. The wells were drilled from 1 to 3.5 miles from shore in water depths ranging from 137 to 290 feet. Natural ocean ice, ranging in thickness from 6 to 8 feet, proved to be adequate to support the weight of the rig, for the average 8-day drilling period, with no problems.
Successful completion of the stratigraphic test program, and the results of a load test conducted on natural ice (discussed later in this paper), led to the drilling of the Panaretie Tenn etal CS W Hecla N-52 well in 1974. The expendable delineation well was drilled to a depth of 3080 feet in a known gas field using a conventional rig capable of drilling to 6000 feet, Because the weight of the rig could not be supported by natural ice thickness, an ice platform had to be constructed.

Geographic Location
The Hecla N-52 wellsite is located in the Hecla and Griper Bay, 1800 miles north of Calgary, 950 miles south of the North Pole and 8 miles east of the Sabine Peninsula on Melville Island, N.W.T. as shown in Figures 1 and 2.
Increased Precision of Porosity Measurements Using a Modified Ruska Universal Porometer
Authors: Taylor R.P. , Wardlaw N.C. 
Published: March 2010

Abstract
Porosity can be determined from bulk volumes measured by mercury displacement in a pycnometer and grain volumes obtained by the "Boyle's law" method. The methods are rapid and the sample suffers minimal physical damage and contamination. Using a Ruska universal porometer, precision and accuracy were found to be dependent on limitations imposed by the instrument, the sample and the operator.
The largest errors are in bulk volume measurements, which are affected by the size and shape of samples and by the way in which the samples are oriented in the pycnometer chamber. Significantly large and unpredictable positive volume errors occur in the pycnometers of porometers and porosimeters because of spaces associated with contacts between the sample and the pycnometer walls or cap which are not invaded by mercury.
With the unmodified instrument and procedure, multiple determinations on a standard of accurately known bulk volume gave POSITIVE errors of as much as 0.1 cc and more. This is a 100 per cent porosity error on a sample of 5 cc bulk volume and 2 per cent porosity. More precise measurements are required for many purposes, and the instrument and procedure were modified and the precision on bulk volume measurements improved to better than ±O.Ol cc; with extreme operator care, it is possible to achieve a precision Of ±0.005 cc. The accuracy of grainvolume measurements was found to be ±0.01 cc.

INTRODUCTION
THE PRECISION and accuracy with which pore volumes can be obtained for rock samples using a Ruska universal parameter are governed by limitations imposed by the instrument, the sample and the operator. In this paper, these limitations are evaluated and instrument modifications and operating techniques for optimum precision and accuracy are described.
The porometer consists of a 100-cc volumetric mercury pump with attached pycnometer. Bulk volumes are measured by mercury displacement in the pycnometer and grain volumes by the "Kobe" or "Boyle''s Law" method. Pore volumes are obtained by subtraction.
The main advantages of obtaining bulk volumes in a mercury pycnometer are that the method is rapid and the sample suffers minimal physical damage and contamination. It can subsequently be used, without further treatment, for the determination of other reservoir properties.
Major problems arise for samples with large exterior vugs, as is the case for many carbonate core plugs, because mercury invasion of the exterior vugs results in low values of the bulk volume. However, exterior vugs create problems for all other methods, with the exception of caliper or micrometer measurement.

Sample Preparation
Cylinders of 2 cm diameter and with volumes of approximately 5 to 8 cc were prepared with a Ruska universal core grinder and drill and were subsequently treated with acetone for 2 to 4 hours in Soxhlet''s apparatus, oven-dried at 80=C for twelve hours and then stored in a desiccator. The samples were weighed before and after determinations in the porometer as a check on retained mercury.