bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pool Description And Performance Analysis Leads to Understanding Golden Spike's Miscible Flood
Authors: Reitzel G.A. , Callow G.O. 
Published: March 2010

Abstract
Reservoir description was a key factor in analyzing the performance of the Golden Spike vertical gravity controlled miscible L.P.G. bank scheme. Understanding the performance of the pool was enhanced by including a detailed reservoir description in a computer model study of the miscible scheme. The originally designed 7% pore volume L.P.G. bank was injected between the gas and oil zones from 1964 through 1975. Extensive monitoring of fluid distribution in this 1,385-acre, 480-foot-thick reef complex indicated that the miscible flood improved the oil recovery until 1979. A geological study, incorporating data from infill wells drilled during the 1970's, shows that the reservoir contains many local barriers to vertical flow. Located in the interior of the reef, these barriers range in size from less than 5 to over 600 acres. The barriers were not recognized prior to infill drilling, because the early development wells were drilled mainly in more homogeneous sections of the reefcomplex. Recent performance analysis indicates the barriers resulted in by-passing of oil and loss of miscible flood benefits after 1978. As a result of the loss of miscibility, the pool is currently under gas drive and the miscible scheme has been terminated. Performance analysis results are confirmed by a cross-section computer model study of the pool. The cross-section model also indicates that the vertical flow barriers combined with the designed bank size results in poor sweep efficiency by solvent. However, future sweep efficiency by gas is predicted to be high due to continued drainage of oil off the barriers.

Introduction
THE GOLDEN SPIKE D3 "A" Pool, located 18 miles southwest of the City of Edmonton in Central Alberta, was discovered in 1949 (Fig. 1). The pool is located on the western, seaward side of a trend of productive Leduc reefs. This limestone reservoir is a Leduc-age Woodbend reef complex, covering an area of 1,385 acres. Within the crestal area of 1,000 acres, average oil pay thickness is 550 feet. Initial oil-in-place was 319 MMSTB, with no gas cap or water leg present.
As indicated in Figure 2, the Leduc Formation at Golden Spike is divisible into three members, designated Lower, Middle and Upper Leduc, Oil occurrence in the Golden Spike D3 ‘A’ Pool is restricted to the Middle and Upper members which, together, make up the reef complex, The underlying Lower Leduc is a shallow-water carbonate bank, more extensive in area than the reef build-up, but limited in reservoir development. This carbonate bank is not in communication with the oil zone.
Initial production of this reservoir by fluid expansion resulted in a rapid pressure decline. Pressure maintenance by gas injection commenced in 1953. Analysis of the available well data and gas flood performance up to 1963 indicated a relatively homogeneous reservoir. The apparent good quality of the reservoir and the availability of a suitable, inexpensive hydrocarbon solvent (LPG) prompted installation of a miscible flood in 1964 (Fig. 3).
A New Model For Fracture Gradient
Authors: Althaus Voy E. 
Published: March 2010

Abstract
For the past eighteen years, fracture gradient has been thought to be some junction of overburden stress, horizontal stress und internal fluid pressure. Each author that has published in the intervening years has refined this idea. This paper derives such a model, but then uses the same data to turn the entire relationship around to derive (and support a new model with the following attributes.Fracture gradient is equal to the least stress field n the earth.Fracture graadient is independent of the fluid pressure gradient; it depends only on the earth's stress field.Fluid pressure gradient is dependent on fracture gradient. If the fluid pressure gradient equals the fracture gradient, the earth fractures and the thud is released to permeable beds.Most abnormal fluid pressure systems may be pressured to the fracture gradient at their structurally highest point.

Introduction
SINCE the puhlication of Hubhert and Willis(11) on hydraulic fracturing in 1957, most authors have held that fracture gradient is a function of overburden stress, horizontal stress and internal fluid pressure, although the exact relationship has remained in dispute. A recent article, however, by MacPherson and Berry(12) states that in calculating fracture gradient from sonic and density logs, they found no evidence that the formation fluid pressure gradient affects the fracture gradient. This strikes a sympathetic point with this author and the result is this paper.
The data gathering and the original curve fitting for this project were done in 1967; but because a number of papers were published that year on fracture gradient, one more paper giving essentially the same results did not seem warranted. The original work is included; however, the purpose of this paper is to show that the same data that were used to relate fracture gradient to pressure gradient can be used to turn the entire equation around and relate pressure gradient to fracture gradient as the independent variable. This solution suggests that fracture gradient is dependent only on minimum regional stress. A body of theory has been derived that indicates that this solution is possible.

Sampling Procedure
The sample for this project included most of the lost returns encountered by Exxon while drilling in South Louisiana and the Louisiana Offshore from 1964 to mid-1967. A total of sixty-six cases were used, which is considered to be a statistically satisfactory sample. The geological section sampled ranged from Lower Miocene to Recent in age, with the bulk of the data being Upper Miocene.
A basic assumption was made in gathering data that the point of fracture in each well was at the highest exposed depth and the lowest exposed formation fluid pressure below the deepest casing set in the well at the time of lost returns. As no cases were 'found in this sample where the formation fluid pressure decreased with depth, the fracture point was picked in all cases as the first exposed point below casing.
A Role For Nuclear Energy In the Recovery Of Oil From the Tar Sands of Alberta
Authors: Puitagunta V.R. , Sochaski R.O. , Robertson R.F.S. 
Published: March 2010

Abstract
This report briefly describes techniques of oil recovery from the tar sands and the energy requirements of this operation. Fossil fuel, such as coal, and CANDU* nuclear reactors are examined as competitive sources of energy for the tar sands plants. This study indicates the feasibility of both sources. Among the nuclear reactors, the organic-cooled version of the CANDU reactor appears to have the necessary flexibility to fit into many of the possible methods of recovering oil from the tar sands.
Cost comparisons of fossil and nuclear sources show that, for the supply of process steam, the nuclear source is competitive under the criteria of debt financing or low discount rates on capital, continued escalation, and long plant capital write-off period.
A strategy is discussed for the recovery of oil from the tar sands with a view to optimizing the costs and, in tile long run, to conserving the fossil fuels at the expense of nuclear fuels. This scheme involves supplying process heat and electricity from organic-cooled CANDU reactors (CANDU-OCR) built at the tar sands site, making hydrogen from coal at the coal fields and piping it to the bitumen upgrading plants. This strategy would require further development of the CANDU-OCR.

INTRODUCTION
Liquid fuels are the form of energy best suited to power the transportation sector, which represents about 25 percent of the total energy consumed in Canada (Present liquid fuel consumption actually exceeds 50 percent of the total energy consumed in Canada). No economic alternative to these fuels has yet been found. Currently, these liquid fuels are derived from petroleum which is expected to be in short supply in theory near future. Recently Canada became a net importer of oil and this situation is expected to continue at least for a decade at a continually increasing rate. The current high prices of crude oil in the international market and the unreliability of the supply are great incentives for any country to become self-sufficient in oil.
Canada has large supplies of tar sands bitumen, coal, uranium, and thorium. It is theoretically possible to convert the energy from any of these fuels into liquid fuel energy. The efficiency, complexity and the capital expenditures required to achieve these conversions vary with the source of energy. For example, no more than 10 percent of the energy in nuclear fuels can be obtained as liquid fuel energy in tile direct cycle which is:
Similarly, two-thirds of the energy content of coal is lost in the process of making liquid fuels from coal.In comparison, only a third of the energy content islost when liquid fuels are derived from the tar sands with present technology. The lower efficiency conversion cycles discussed are complex and require high capital investments.
Recovery of liquid fuels from tar sands involves an energy input in the form of electricity, process heat, and hydrogen.
Automatic Kriging And Contouring In The Presence Of Trends (Universal Kriging Made Simple)
Authors: Davis Michael W.D. , David Michel 
Published: March 2010

Abstract
The main purpose of this paper is to present a new automatic interpolation and contouring technique which automatically recognizes the spatial structure of the dam to be contoured even when, trends are present and data are not regularly spaced. A brief relief of contouring problems is presented the idea of spatial structure and its characterization by a generalized covariance is then introduced and the POLYPAC program is described. Applications in various areas (oil shales, sulphide mines, coal field, cement industry, geophysical data) are illustrated and a detailed appendix covers the mathematical theory of the intrinsic random functions of order k, which is the basis for the program. References to other similar programs are included.

Conceptual Background

Introduction
Attempting to survey everything that has been written on the subject of automatic contouring is a challenging task as ideas are generated in various fields with little communication between each other, such as coal reserves, ore reserve estimation or geophysical mapping, not to mention geography and meteorology. Also, the concern of contouring packages for high cosmetic quality like G.P.C.P., CSPL. Stampede, etc... tends to push people away from the fundamentals of the problem and its conceptualization, Most of the time the interpolation method used in a program is unknown to the map user, or he is left with the choice of up to 32 different interpolation subroutines in the same package, with no further hint at which method is adapted to his problem. It is our opinion that most mapping problems can be encased in the frame of a unifying theory which will allow the generation of the most adequate map for a given purpose. This theory has been known as kriging or simply geostatistics and was developed by Matheron, The full name of the most complete version of it is "theory of intrinsic random functions of order k", and all its intricacies have now been turned into another black box, which produces the best theoretical maps within the framework of distance weighted and trend-surface interpolation. It is one of the purposes of this paper to show which concepts are needed to understand why a given interpolation algorithm is good in certain cases and unacceptable in others. These concepts of spatial structure, drift, trend, high-frequency noise, estimation variance have been known for a long time, but we must admit that map users should be presented with something else than a truckload of equations. The contouring problem is easily split in two; the first problem is that of the generation of II. regular grid of points, the second being that of aesthetically contouring this fine grid. So far only the first problem retained the attention of geostatisticians, with few exceptions. Broken contours are not acceptable even if the theory behind the grid generation technique is faultless (Olea, 1972). There now exists a program matching the most sophisticated theory and superb contours.
Analyzing Well Performance X
Authors: McCoy James N. 
Published: March 2010

Abstract
After a general discussion of fluid flow, this paper reviews the data which are necessary for well analysis. The acoustic liquid level instrument is described, well producing rate efficiency (with and without gas) is discussed and an analysis of downhole equipment is given.

Introduction
Analyzing well performance is an important step toward increasing profits by improving production techniques. The analysis is made by field tests and examination of well data. The acoustic liquid level instrument offers valuable information, because downhole pressures can be determined from the depth-to-liquid measurement.

Fluid Flow (generalized)
Fluid flow in a reservoir is caused by movement of fluid from a high-pressure area to a low-pressure area. Fluid flow into a wellbore occurs when fluids, present in the wellbore are removed so that the pressure is decreased. Then? fluid from an area of higher pressure flows into the lower-pressure wellbore (Fig. 1).
Fluid flow into a wellbore is approximately proportional to the drawdown pressure, which is the difference in pressure between the higher pressure reservoir and the low-pressure wellbore. The greater the difference, the greater the fluid flow. Figure 2 represents some ideal cases of fluid flow in a reservoir.
The lower the wellbore pressure the greater the inflow rate. Generally, in the past, the inflow rate has been assumed to be proportional to the drawdown pressure. This procedure is still used in wells which produce liquid without gas. Vogel(I) presents a curve for predicting flow rates in 2-phase flow (liquid and gas). This curve is shown on the Well Analysis sheet and should be used when predicting flow behaviour in wells making liquid and gas.

Necessary Data for Well Analysis
Four factors are extremely important in analyzing well performance:static bottom-hole pressure (or reservoir pressure),producing bottom-hole pressure,well test andpump capacity.
For maximum withdrawal, the producing bottom-hole pressure must be low compared to the static bottom-hole pressure. A producing bottom-hole pressure of 75 psi is low compared to a static reservoir of 2300 psi, and practically all of the production is beng obtained. However, if the static reservoir pressure is 100 psi, approximately one-fourth of the production is being obtained. The well test must also be known. If the producing wellbore pressure is low compared to the static reservoir pressure, maximum inflow is occurring. However, if the maximum inflow is less than commercial production, action must be taken. Last, the pump capacity must be known. If the pump capacity is not matched suitably to the well's production, excessive wear and a mechanical loss of efficiency are occurring if the pump capacity greatly exceeds the production rate. A production loss occurs if the, pump capacity is less than the well's producing capacity.
Note the importance of each item, by trying to determine the proper action on each of the wells in Table 1 when only one of the four items on each well is omitted.
Wellbore Transmission Of Electrical Power
Authors: Newbold F.R. , Perkins T.K. 
Published: March 2010

Abstract
In-situ electrical heating of viscous oils depends on the passage of large electrical currents through a subsurface formation. It is essential to the design of such a process to know the percentage of power applied at the wellhead which actually heats the object formation below. This in turn requires that there exist some convenient and reliable method for predicting the power loss which occurs in the wellbore. Although the determination of the power loss is straightforward for a DC system, it is often desirable to use readily available AC current to minimize corrosion. On the other hand, use of AC current can lead to a significant increase in transmission power loss in the presence of steel tubular goods, primarily because of magnetic hysteresis and eddy current losses.
It is the purpose of this paper to present an experimental method for determining the wellbore transmission power loss in AC systems. Theory related to AC power loss is discussed, and general laboratory experiments are described which determine the losses in complex wellbore systems. Power loss data obtained from a shallow well test installation are presented for two distinct modes of operation: one in which copper cables are used to conduct power down hole, and a second which utilizes the steel pipe as the conductor. Additional laboratory experiments are then described which were designed to duplicate the data taken in the shallow wells. The laboratory results are shown to be in good agreement with power measurements made in the two 500-foot wells of the shallow well installation, demonstrating that the method can predict power loss for field-scale systems.

Introduction
Electrical heating of subsurface formations has frequently been proposed as a means of enhancing oil recovery(1,2,3) In particular, electrical heating has been proposed(4) as a means for in-situ heating of a subsurface oil sand formation in order to mobilize the viscous oil contained therein. A schematic for this process appears in Figure 1 and is discussed in detail in Reference 4. Basically, the concept is to conduct large AC currents down a wellbore, through the object formation, and back up an adjacent well. Formation brine provides the conductive medium in most of the formations, and "bound" water in the shales accounts for their (high) conductivity. These currents heat the formation by virtue of resistance (Joule) heating, creating a mobile fluid path between the wells where little or no flow was possible before heating. Once the viscous oil has been mobilized, it can be recovered by a more conventional fluid displacement process. Note that although heat conduction will occur and must be taken into account, this is not the principal means by which fluid mobility is achieved. Also note that Joule heating occurs throughout the formation from the moment power is applied so that the critical area midway between the electrode wells is being heated and mobilized from the outset.
The Canadian Outlook And Priorities For Energy
Authors: Scotland W.A. 
Published: March 2010

Abstract
This paper was presented under the "Energy Options" theme during the Plenary Session at the 29tb Annual Technical Meeting of The Petroleum Society of CIM, Calgary, Alberta, June 14.

Introduction
THE National Energy Board is in the midst of a bearing into the supply and demand for oil in Canada, and various related matters, and we will hold a similar enquiry on natural gas supply and demand this fall. A number of matters I will touch on will be the subject of industry and public discussion through the hearing process. Once the hearings are completed, the Board will be in a position to become more specific in its views in these areas. In the meantime, it may be useful for us to consider an overview of certain aspects of the Canadian energy situation.
In recent years, perceptions of the energy situation by industry, the public and government have changed to adapt to the reality that the days of low-cost energy are behind us. All sectors of the economy are now in the process of modifying past practices to bring themselves into line with that reality. The overriding priority in energy at this time is to ensure the availability of an adequate energy supply to meet the needs of a healthy and vigorous economy and society, in order to have an acceptable quality of life in Canada. This includes planning to meet the possibility of an eventual constraint on world oil supplies, which could occur in the mid or late 1980's. This supply constraint could be either physical or political and could cause economic upheaval if energy shortages occur or if world oil prices increase too rapidly. Accordingly, the federal government has set a goal of achieving the highest possible degree of self-reliance in energy.
To meet this self-reliance goal, a whole series of energy policies have been formulated. It is difficult to single out a particular policy as having priority over other government measures, because it is the net effect of the entire set of policies that is intended to allow Canada to meet its self-reliance target. However, increased emphasis has been given to some policy areas and it is this shift in emphasis I will try to outline here.

Increased Reliance

On Oil Imports
A major area of federal government concern is Canada's growing net imports of oil and oil products. In 1975, Canada was self-sufficient in the sense that we exported more oil than we imported. Today, net imports are about 300,000 barrels a day. By 1985, net imports may grow to much higher levels unless action continues to be taken to reduce the rate of growth of oil demand and to increase the level of effective domestic supply. If net oil imports were to reach extremely high levels, this could create difficulties in Canada's balance-of-payments situation, and could be most detrimental to living standards and general economic activity throughout the country.