bluuebunny/crossref_metadata_2025_split huggingface dataset:
Lateral Water Encroachment In the Pincher Creek Field
Authors: Hnatiuk John 
Published: March 2010

Abstract
Unusual water production performance has occurred in a portion of the Pincher Creek Gas Field. This fingering or ‘lateral water encroachment’ from the downdip aquifer has been insufficient to significantly affect pressure performance, but has severely restricted the productivity of some wells and will reduce the recovery of gas in place. Water encroached into one structurally high drilling spacing unit even before the well was drilled and placed on production. The mechanics of this water movement have been confirmed during two reconditioning operations and by the production performance of wells. It has been found that a watered-out well can be made to produce water-free gas by recompleting LOWER in the same continuously porous interval. Relief from water production after reconditioning may be short-lived. The various factors to which water fingering could be attributed have been examined and are discussed. Lithofacies studies indicate two ‘shoals’ which form one continuous gas reservoir. Premature water encroachment at individual wells could be related to interfingering of rock types and lack of vertical permeability. This water encroachment phenomenon could be effective to varying degrees in other deep, fractured reservoirs in Alberta.

INTRODUCTION
The Pincher Creek Rundle Gas Pool, located in the extreme southwestern corner of Alberta, as shown on Fig.1, was discovered at a depth of 11,700 feet by the drilling of Pincher Creek No.1 in 1947. Subsequent drilling resulted in twenty-four gas wells and three dry holes. Figure 2 is a structure map which shows the locations of the wells.
Commencing early in 1957, the pool was cycled at a raw gas rate of 60 MMcf/D for two years to recover sulphur and condensate. In late 1958, gas sales to Trans-Canada commenced.
Water production problems have adversely affected the deliverabilities of wells in the northern half of the field, some occurring very early in the blowdown operation. The primary purpose of this paper is to discuss the unusual water production performance and remedial measures.

RESERVOIR CHARACTERISTICS

Geology
The Pincher Creek sour gas – condensate reservoir consists of a fractured thrust block of Rundle strata striking N3 °W and dipping 4 to 8 degrees to the southwest. The areal extent of the pool is determined by the down-dip aquifer on the west and by faults that bound the eastern edge of the structure, as shown schematically on Figure 4. Two wells appear to have encountered separate fault blocks which are in pressure communication with the main reservoir. The productive portion of the Rundle can be subdivided into five zones, the Upper Dense, Upper Porous. Middle Hard, Crystalline and Lower Porous, each differing in lithology, thickness, porosity and permeability. The five zones form a continuously porous reservoir which is normally 550 feet thick when the entire section is above water and not faulted. In general, the lithology of the pay section is one of dolomite above the Crystalline Zone and of variable amounts of limestone and dolomite through the remainder.
Education Needs of the Oil Industry's Engineering Staff
Authors: Smith Charles R. 
Published: March 2010

Abstract
From the humble beginning of the oil industry at Titusville, Pennsylvania in 1859 to the giant that it is today, the use of the professionally educated individual has been a mainstay of the energy business - be this in companies, in governmental agencies, in consulting groups or in the universities. The dominant role of the engineer dictates that he lie current and he capable of adjusting to the evolving technology. Responsibility of continuing and renewal education lies with the individual, with needed support from the employer, from the professional societies, from the universities and from the various entities that provide educational services. There is reason to believe that an arbitrary two-week re-education period per year, with a sabbatical leave of six months (minimum) every five years, should be the goal of the aggressive engineer, the requirement of each and every employer, and the personal goal of each self-employed engineer. Additional regional continuing education centers need to be established - similar to the Kellogg Center at the University of Oklahoma.

INTRODUCTION
MUCH HAS BEEN SAID about the state of the engineering profession - especially after the launching of the first Sputnik. Since this historic date in 1957, the applied sciences received much attention and considerable federal funding, although not necessarily in areas directly benefiting the oil industry, However, the United States' emphasis on space technology did culminate in the landing of two men on the moon in July of 1969. With less journalistic impact, but with more direct benefit to the man on the street, the oil industry has managed to provide the world with all economical energy source that has primary changed lives for the better. Of the problems that have been created, pollution is now receiving the most attention. Much of the solving will be done by engineers of all ages, but mainly by those who have remained mentally flexible and who have kept on top of, or at least current with, advancing technology. Where did it all begin?

BACKGROUND
It may be speculated that education began with the drilling of the Drake well in Titusville, Pennsylvania, or possibly before this date. A sizeable patent literature existed prior to 1900. Uhl(1) points out that by the early 1900's, engineers and geologists were transmitting to their apprentices, through articles and through informal courses and study groups, the knowledge gleaned from the actual drilling for and the production of oil and gas. Early AIME and USGS publications became the main recorders of such activities. In 1910, the University of Pittsburgh established the first formal curriculum to satisfy, in part, the growing technical needs of the oil industry. The first petroleum engineering degrees were granted in 1915. By, June of 1970, approximately 15,000 petroleum engineers will have graduated from the 27 universities and colleges with petroleum programs in the United States. These graduates have come from and returned to serve most of the oil-producing countries of the world.
Unit Equity Determination
Authors: Tetreau E.M. , Roberts L.E. 
Published: March 2010

Abstract
Where unitization takes place early in a pool's life, it is considered critical that the evaluations determining participating equity be carried out quickly and accurately, Comprehensive study of the inter-relationship of all of the known variables, or commonly called unitization parameters, for a large number of land tracts with a wide variance of parameters has in the past been unwieldy and impractical. In order to assess accurately- the impact of these unitization parameters, a computer program was developed to calculate future performance and tract value. The example used in this illustration happens to the for a unit project in the Province of Alberta, but the principle and procedures can be adapted to any project where contributory values of the tracts involved need to be assessed. The pro-gram includes the following features:Pool allowable forecast as a time function.Distribution of pool allowables on an acreage basis, together with redistribution of individual tract's incapability to the remaining capable wells.Crude oil price as a function of time.Present worth at several discount rates.Individual tract's reserves and allowable acreage.Individual tract's initial producing capacity start of decline, type of decline (constant percentage harmonic or hyperbolic) and abandonment rate.Operating costs and expenditure scheduling.Complete print-out of tract performance over 50 years.Each company's participation equity at each discount rate.
The adaptability of the program has been demonstrated by the virtual fieldwide unitization of the Nipisi Gilwood pool in Alberta. Here, twenty of the twenty-one operators with both wholly owned and joint interests in various parts of the pool, and under a system which grants equal allowables to all productive acreage, were able to agree despite major variances in their parameters.
It is no longer necessary then to rely on previously established unitization weighting patterns of various parameters to establish unit equities.

INTRODUCTION
IMPLEMENTATION of Alberta's reserve proration system in May, 1968 necessitated a review of both the parameters and their proper weighting in unitization studies. Where in the past each pool was typically developed to the same density, the regulations now in force permit spacing to range from 160 to 1,440 acres. Although the allowable within a pool remains distributed on validated acreage the proration system is now designed to transfer individual well in capabilities back to the pool's remaining capable wells. The situation is further complicated in that owners of tracts with wide spacing have the opportunity of infill drilling for productivity to a density of IGO acres/well.
Shortly after the new system was announced, it became evident that the earlier practice of arbitrarily weighting allowable rate and reserves wasn't answering such fundamental questions as:What is the effective impact of allowable redistribution within the pool?What effective weighting should be given to rate under the new proration system?Who should be responsible for infill drilling investments?
Stimulation of Thick Mississippian Carbonate Sections In Foothill Wells
Authors: Nielson G.W. 
Published: March 2010

Abstract
This paper will review the development of the Quirk Creek gas field and the techniques used to drill, complete and stimulate the comparatively thick heterogeneous Mississippian sections found in the earlier wells. It will discuss the disappointing results obtained from these conventional stimulation treatments, and describe in detail the systematic efforts subsequently made to improve the deliverabilities of individual wells by selective and largeyo1ume acid-fracturing treatments.

Introduction
IN JUNE 1967, the first Quirk Creek well was spudded by Columbian Northland on a farm-in from Imperial Oil. In August 1967, the Missippian reef was penetrated and proved to be gas-bearing. Seven of the next eight wells also produced gas. This paper describes the original completions of the first four wells, and the remedial stimulation treatments subsequently used to increase their deliverabilities.

Description Of The Field
Quirk Creek is located 25 miles southwest of Calgary, near the north end of the Turner Valley Pool (Figure 1).
The current pool size is illustrated in Figure 2, which shows the eight potential gas wells and the one dry hole. The field boundaries are defined by a fault to the northeast and a gas/water contact to the southwest. This forms a banana-shaped structural trap, the ends of which are limited by both a gas/water contact and a tightening of the formation. The better wells are located near the center of the field, where the gas plant will be built.
The Mississippian reef is 600 feet thick and consists of massive limestone beds interspersed with dolomites. The porosity, ranging from that caused by very small vugs to minute inter crystalline porosity, is generally found in the dolomite. Some vertical fracturing has been noted in the cores.
The net pay varies in thickness between 125 and 175 feet, and is scattered throughout the reservoir in isolated stringers as shown in Figure S. These stringers range in thickness from 2 to 50 feet, with porosities of up to 19 per cent and an over-all average of 8 per cent over the productive intervals.
Low permeabilities characterize the reservoir. The average is 1.25 md, although individual streaks may reach as high as 100 md, The bottom-hole temperature at 120 °F is abnormally low the bottom-hole pressure is 2,200 psi. The average depth of the wells is 6,550 feet.
The gas is moderately rich in condensate, ranging from 9 to 11 barrels per MMcf of gas. The hydrogen sulpbide content ranges from 8 to 10 percent.

Original Completion And Stimulation Techniques
The completion techniques used in the first four wells – 6–5, 11–33, 10–28 and 11–11 – followed recognized gas-well completion practices and are summarized on Table 1. In most cases, the well bore was evacuated with nitrogen, then perforated with one or two holes in each permeable internal as determined from micrologs and core analyses. The total number of perforations per well varied from 36 to 88, depending on the total thickness of the pay and the number of porous stringers.
A Current Review of Forward Combustion
Authors: Flock D.L. , Dranchuk P.M. 
Published: March 2010

Abstract
In-situ combustion methods of oil recovery generally involve heat transfer with phase change and chemical reaction coupled with the hydrodynamics of multi-phase flow through porous media. To date, a vast amount of work has been carried out in this area and a. number of successful projects have been reported.
This paper examines only a portion of this field. It presents an over-all view of the forward combustion process by reviewing the results of some of the key experimental and theoretical studies and field tests.

Introduction
ALTHOUGH THE FORWARD COMBUSTION PROCESS may be described by means of an intricate ensemble of a number of individual physical and chemical processes, the over-all mechanism has been initially described simply as follows. The process is initiated by injecting air for a short period, so as to establish a continuous gas phase between the injecting- and producing wells. Once this is accomplished, heat is introduced into the injecting well so as to raise the temperature of the formation in the vicinity of the wellbore. When the formation temperature has been raised sufficiently, the formation oil, in vicinity of the wellbore, is ignited. As air injection continues, the burning gradually progresses from the injecting to the producing well When burning stabilizes, the process may be described by means of a series of zones, as is shown in Figure, 1. In short, this series consists of a? burned zone, a combustion front, a hot water zone, a light hydrocarbon zone, an oil bank and an original or unaltered zone.
At the Fifth World Petroleum Congress, Tadema(1). using the results of recent investigations(2), (3), (4) proposed a more detailed representation of the over-all mechanism, as is shown in Figure 2. In his representation, the series of zones consists of a burned zone, a combustion zone, a multiphase zone, a three-phase zone, an oil bank zone and an original zone. These zones contain air, coke, (steam, gases, hot water and light hydrocarbons). (gases, oil and water), (oil and gas) and original oil, respectively.
According to this model, the temperature distribution assume the shape of a heat wave and is characterized by a peak temperature in the combustion zone, a steep front followed by a steam plateau downstream, and a graduate decline upstream. In general, the heat-wave propagation velocity does not appear to be influenced b:v oil or rock type hut is directly related to air flux and oxygen content. That is as air flux and oxygen content are decreased the temperature profile tends to elongate.

The Combustion Zone
In the multiphase zone, crude oil is vaporized and cracked or carbonized to produce a residuum or coke deposit on the sand surface. This deposit serves as fuel in the combustion zone. Heat is then carried forward by convection by the water resulting from combustion, vaporized formation water hot gases and combustion products.
Generally the peak temperature in the combustion zone varies between 700 and 1,000 °F. Combustion itself is believed to occur in two steps.
Arctic Engineering For the Petroleum Industry
Authors: Hemstock R.A. 
Published: March 2010

Abstract
THE ARCTIC has been defined in a variety of ways by latitude or tree line, by isotherm or permafrost. For this paper, it will be considered simply as that part of Canada lying north of the 60th parallel. Most of what is discussed here will apply specifically to the sedimentary basin, the prospective oil country bring in the Northwest Territories; other countries, however, also have very prospective arctic areas, and many of their problems will be similar (Figure 1).
Long before the current surge of interest in the north, major construction projects had been successfully undertaken in arctic Canada. One of the most outstanding was a railway from Skagway to Whitehorse: built seventy years ago, it is still hauling freight and is an important part of the transportation system supplying the Yukon Territory. In northern Manitoba, the Churchill railway was begun in 1910, through most difficult permafrost conditions. War halted construction for a time, but the line was completed in the late nineteen twenties. Since then we have had various hydropower developments, the construction of major transmission lines and, in the military field, the Early Warning system and the DEW line. The oil industry development along the Mackenzie was started over 50 years ago, and an outstanding achievement during the war years was the construction of some 660 miles of pipeline from Norman Wells to Whitehorse. These represent only a few of the major construction projects on which, over the past several decades, nearly five billion dollars has been spent.
The engineering problems discussed here will be those that are unique to the north. They include climate, permafrost, ice and snow, terrain, and remoteness. Although these problems are not new to Canadian engineers, when they have to be faced together they call for new approaches to the engineering development of large-scale oil and gas reserves. To add to the challenge, these developments are going on at a time when everyone is aware of "ecology" and "pollution" as matters of grave public concern. Development of northern Canada will go on, but every effort must be made to establish a proper balance between resource development and environmental protection. This paper will outline our present state of the art and suggest some new approaches to work that will be required.

Climate
We share our Canadian arctic climate with Russia, Alaska and the Scandinavian countries (Figure 2). In winter it features intense cold, high winds and darkness, in summer long hours of daylight and very little precipitation – so that without the permafrost, the Canadian arctic would be largely a desert. Although we have most of the know-how to be able to design equipment suitable for these conditions, very often what is available has been made for warmer climates and simply moved north for its useful life. We should not be surprised, then, if it performs badly, or fails from such causes as brittle fracture of steel.
A New Era In Supervisory Control
Authors: Niven Robert D. 
Published: March 2010

Abstract
Supervisory control technology has; entered a new phase of development and application. Swept along by the explosive development in integrated circuit technology, minicomputers high-speed I/O devices and long-distance data communication, supervisory control has reached a level of reliability and sophistication whereby it can perform previously unthought-of tasks. Couple this rapid development with the fact that supervisory control is about to cross over into a new domain, the inaccessible and hostile environment of the North, and it is possible to foresee almost limitless applications in the future.
Recognizing the rapid technological growth and challenge of the North, supervisory control manufacturers, including the manufacturers of communications systems, flower steams and end devices, are looking into developing system hardware and concepts to meet this challenge. Because of the extremely high operating costs of production and transmission facilities in the North, and the ever-decreasing cost of supervisory control hardware, producing companies must start considering the use of supervisory control in their operations. They must further train their staff in the acceptance of supervisory concepts and in the operation and maintenance of the hardware.
The purpose of this paper is not to show "pie in the sky Concepts which may exist ten or fifteen years from now Its purpose is to bring- the engineer up-to-date in what has transpired in supervisor control over the last three years, what is available now and how modern concepts and hardware can be applied to supervisory system of the future - and the North.

Supervisory Control Brought Up-To-Date
THE term "Supervisory Control", as it is understood by the oil and gas industry, is the capability of having complete data monitoring and control of a remote system or systems from one central point. From the inception of supervisory control in the late 1800's, many thousands of designs have evolved to achieve this end, each with its own particular advantage and specific application.
Practically all the original development 'work on supervisory systems was carried out by the telephone companies. In fact, much of the early work was based on the telephone exchange installed in Laporte, Indiana, in 1892, by the Automatic Electric Co. Development work was carried on into the early 1900's, with the dial telephone becoming the first truly digital supervisory system. By dialing a number it was possible to ring a bell at some specified remote location. The next obvious step was to replace the bell with a relay to open and close it valve or start and stop a motor. This method of digital control, and methods which evolved from it, has been used extensively up to the present day in many industrial applications. However, its relatively slow speed and susceptibility to errors make it unacceptable in most modern-day applications.
Alarm monitoring, which is a fundamental feature of all supervisory systems, was first implemented in a system developed in 1921 by J. B. Harlow.