bluuebunny/crossref_metadata_2025_split huggingface dataset:
Northern Oil Prospect Re-Examined
Authors: Quirin G. David 
Published: March 2010

Abstract
This paper updates a study made five years ago, reviewing the main points and noting how changed conditions may affect the economies of oil production inthe Arctic Islands and the northern mainland. Wellhead prices and possiblemarkets are estimated; offshore development is a new factor. The paper concludes with a consideration of the effects on Prairie production and possible government controls to regulate oil production in the North.

Introduction
I have dealt at length, in a monograph, with the basic factors affecting the feasibility of oil and gas development in northern Canada (1). That study was prepared five years ago, and conditions have changed. The purpose of this paperis to review the main points made in my earlier study, and to see how changed conditions may have affected the prospects for northern oil development. The development of any natural resource industry in a given geographic setting isthe result of a partly fortuitous, partly controllable combination of factors physical, technological, political and economic - which together make possible the profitable exploitation of the underlying resource. Emphasis must be placedon the word profitable, for development which is not profitable is sheer waste, puts more into the ground than will ever come out, benefits no one, and is unlikely to be viable in the long run. I propose to review these factors briefly as they apply in this case.

Physical Factor
As the underlying basis for the development of any natural resource industryis the resource itself, I will examine the physical factor first. Compared withthe state of our knowledge five years ago, our knowledge of the intimatepetroleum geology of the Canadian North has increased enormously, thanks to thedrilling programs carried out in the intervening period. However, it would bemore accurate to say that what has been achieved is a slight reduction in ourenormous ignorance. We've had a few surprises, and perhaps found a few placeswhere the oil isn't, and we can expect to find a few more of these before wefind out where the oil is.
General Geology of Lower Cretaceous Heavy Oil Accumulations in Western Canada
Authors: Vigrass L.W. 
Published: March 2010

Abstract
Lower Cretaceous sand reservoirs contain about 750 billion barrels ofviscous, heavy oil along a broad arcuate belt that extends from northwestern Alberta into west-central Saskatchewan. The heavy oil is pooled in the Mannville Group and, in a gross sense, occurs in a marine-continentaltransition facies. The accumulation at Peace River is in a regional onlapfeature. The accumulations in the Athabasca-Lloydminster region occur acrossthe crest and on the southwest flank of a regional anticlinal feature associated with the solution of salt from Middle Devonian beds. These regional features had already formed by the end of Early Cretaceous time.
Chemical and physical properties of oils from different accumulations show that they belong to a single oil system and suggest a common mode of origin.The Athabasca oil is young and immature and not evaporated, altered orpolymerized. The oil is not escaped and re-deposited Devonian oil. The mosttenable working hypothesis is that hydrocarbons moved out of sediments in thedeep basin in micellar solution in compaction waters. The hydrocarbons weredeposited as heavy asphaltic oil where physical-chemical conditions weresuitable. Early formed stratigraphic and structural "traps" served as loci of deposition for the heavy oil. Since deposition, and governed by buoyancy and capillarity, there has been some adjustment in position of the oil inthe traps.

Introduction
This paper concerns the geology of the main belt of Lower Cretaceous heavyoil accumulations in Western Canada. It is hoped that the regional approach that is used will improve our understanding of the individual accumulations and will aid in their exploitation.
The main Lower Cretaceous heavy oil belt extends as a 600-mile arc from Peace River in northwestern Alberta to Lloydminster in western Saskatchewan(Figure 1). The total amount of heavy oil reservoired in the sandstonesof the belt is immense, totalling at least 750 billion barrels of oil-in-place.About 95 percent of the known oil occurs in the Athabasca, Peace River, Wabasca and Cold Lake deposits.
Economic Considerations Concerning the Use of Salt Caverns for Natural Gas Storage by an Integrated Natural Gas Transmission and Distribution System
Authors: Clipsham W.B. , Olafson D.G. , Pratt B.G. , Steuart B.A. 
Published: March 2010

Abstract
The system under discussion, that of the Saskatchewan Power Corporation, transmits and distributes natural gas to customers whose numbers are small inrelation to the transmission distances involved. The severe continental climate coupled with the long transmission distances make the expense of meeting the peak demands imposed on the system particularly onerous. Although the systemhas available depleted gas fields that are satisfactory for storage, both in adeveloped and in a potential state, none of these reservoirs are close enoughto the load centers to alleviate the demand on major transmission systems.
Much of southern Saskatchewan is underlain by the Prairie Evaporite formation, which consists mainly of potassium and sodium chlorides. This formation occurs in thicknesses of up to 600 feet, and at depths ranging from 2,500 to 7,000 feet.
The Corporation has undertaken to develop natural gas storage in caverns that have been washed from the Prairie Evaporite formation by a solution mining process. Two of these caverns are presently in operation, and a third is in theprocess of being washed out. The economic considerations for developing these caverns are quite different from the considerations governing the development of a conventional storage field. The differences in these considerations arise, first, from the fact that the size of the reservoir is controllable and, secondly, because this type of reservoir has a relatively limited total volume compared to its delivery capability. This paper will outline the techniques bywhich the Corporation has attempted to analyse the relationship between pipe-line capacity arid cavern storage volume in order to fulfill the system requirements at minimum cost.

The Corporation's System
The Saskatchewan Power Corporation's natural gas transmission system extends throughout the populated area of Saskatchewan. With service to all of Saskatchewan's cities and most towns, the total number of customers served at year-end 1964 was 105,251.
Helium Prospects for Canada
Authors: Reed G.A.D. 
Published: March 2010

Abstract
Helium is a space-age engineering material used for: the refrigeration ofcommunications equipment (telestar); welding space-age metals such as titaniumand magnesium, as well as aluminum; and as a heat transfer medium inexperimental atomic reactors. It is also used in shock-tube tests, leakdetectors, as a carrier gas in chromatographs, in space simulators, inmeteorological balloons and in upper air research. Canadian helium is marketedon a world-wide basis. It is produced in Saskatchewan by the liquefaction of agas mixture which is principally nitrogen. Shipping helium in liquid form may provide sufficient savings in handling costs to reduce the cost to theconsumer.

Introduction
Canadian helium prospects are related particularly to the sole Canadianproducer, in fact the sole helium producer in the Western World outside the United States. Canadian Helium Limited, with a recovery plant located near Swift Current, Saskatchewan.
Helium is an inert rare gas, and the second lightest element known. Prof.H.J. Lockyer, the astronomer, discovered it 97 years ago in the spectrum of thesun, and in 1905 researchers at the University of Kansas identified it innatural gas. The era of the space age and the demands for atomic energy, however, have elevated helium from a role as simply a balloon-filling gas tothat of an exotic engineering material.

Markets
There is a market for helium in nearly every industrialized country of theworld. Russia supplies the needs of the communist world. Until the Canadianplant went onstream in late 1963, all of the free world's supply of helium wasprovided by the United States. Since the first world war, helium has been astrategic war material and the United States has restricted its export. Infact, export licences approved by the Secretary of State are required. As lateas 1962, the amount exported from the U.S. for approved scientific and medicaluses was approximately 9 million standard cubic feet, with more than 3.0 million cubic feet going to Canada.
The Offset Obligation in the Oil and Gas Lease
Authors: Nelles R.B. 
Published: March 2010

Abstract
This paper includes an analysis of the offset clause contained in most oiland gas leases, with particular emphasis upon the implications of the newproduction spacing units.

The Need for an Offset Clause
Petroleum and natural gas are of a fugacious nature, and, being lighter thanthe water that is present in porous strata, migrate up dip and accumulate whenentrapped by a permeability barrier. If there is static pressure in thereservoir, there will be no migration of the hydrocarbons. However, if there isa pressure change, such as a well piercing the reservoir, there will bemigration to an extent which would depend on the porosity and permeability ofthe reservoir rock as well as on the degree of the pressure change. Thehydrocarbons will move toward the point of low pressure. Under thesecircumstances, it is conceivable that if production is taken from a well onland owned by lessor A, hydrocarbons underlying land owned by lessor B couldmove to a position under A's land and be brought into A's possession, there by diminishing the quantity of petroleum and natural gas under B's land.
It becomes apparent that the lessor must ensure that the lessee doeverything he can to prevent hydrocarbons from being drained by others fromunder the lessor's land, and the most effective way a lessor can protect hisinterest is to have the lessee drill a well on his own land and produce thehydrocarbons before they have been produced through the well on the adjoiningpremises. This need to protect against drainage has given rise to a drillingcommitment, often incorporated in oil and gas leases, known as the "offsetobligation." This requires the lessee to commence drilling within a specifiedtime from the time that production in commercial quantities is obtained on theadjoining lands.
Engineering for the Petroleum Industry in the Arctic
Authors: Hemstock R.A. 
Published: March 2010

Abstract
Experience in Western Canada has shown that we can work effectively in themost severe climate, and so the question is no longer can the Arctic bedeveloped - but rather, how can it best be done. Transportation, logistics, communications and planning are key words in describing successful Arcticdevelopment.
Transportation is probably the most costly single factor in northern work.This is due partly to the lack of modern transport means in the north, andpartly to the seasonal nature of some methods of transport, e.g., inlandwaterways, but it is mostly due to the great distances involved.
Geological work is being done very well by helicopter and small fixed-wingaircraft. Geophysical work is being carried out using tracked equipment eitheryear-round or on a seasonal basis, with trucks being used in the winter.Wildcat drilling has been quite comparable to that in other areas of Western Canada, except for the high cost of transportation.
Permafrost, which underlies the Arctic and most of the sub-Arctic, resultsin special engineering problems for foundations, water supply, road building, etc. Methods are available for handling these, although we have much to learnin optimizing the engineering solutions.
Modern oilfield technology can be applied in the Arctic, and suchdevelopments as automation will be essential in the economic development ofnorthern oil.

Introduction
This paper will outline and suggest possible solutions for some of theengineering problems that affect the development of oil reserves in an Arcticor sub-Arctic environment. The theme might well be summarized by quoting Dr.John C. Reed, director of the Arctic Institute of North America, who says: "Thelimitations of northern development are largely the limitations of knowledgeand experience and not limitations of environment." There is much to be learnedbefore we can be sure we have the best engineering answers.
Alberta Proration - A Year of Transition
Authors: Strom N.A. 
Published: March 2010

Abstract
This paper outlines the Alberta Oil and Gas Conservation Board's new planfor prorating crude oil production in Alberta. A review of the objectives ofthe new plan, the deficiencies of the old plan and the changes adopted is firstpresented, and then the implementation and effects of the plan are discussed.Sections of the paper are devoted to well spacing changes, maximum ratelimitations and recovery efficiency, and the achievements noted in the earlystages of the plan are listed.

Introduction
Pursuant to its report concerning proration issued in July, 1964, the Alberta Oil and Gas Conservation Board took steps to implement a new plan ofprorating crude oil production in Alberta commencing on May 1, 1965. Theprocedure of conversion to the new plan provided for a four-year transitionperiod culminating on April 30, 1969. Nearly one-quarter of the transitionperiod has passed, and this paper reviews, at least in part, the effects of themeasures adopted in the new plan.

Review
The following is a brief review of the objectives aimed for in the new plan, the deficiencies of the old plan, and the actual changes adopted to foster theobjective and overcome the previous deficiencies. In addition to the explicitstatutory objectives, which need not be repeated here, the objectives sought inthe new proration plan include the following:the encouragement of efforts to enhance recovery from pools;the deferment of the abandonment of wells until all apparently economicallyrecoverable oil has been produced;provision for the production of low-reserve-per- acre discoveries whichappear to contain economically recoverable oil;to provide a system which is relatively simple to administer;to provide a method of allocation operable over a wide range of marketconditions, both as to supply and demand, and allow continuity in theproduction from and development of pools;to encourage exploration and not deter any party interested from exploringfor new reserves;to maintain the participation in the industry by anyone interested;andto encourage the economic optimum development within pools, and minimizethe cost of drilling and producing oil.
A Theoretical Comparison of Heat Transfer into Porous Media by the Injection of Steam or Hot Water
Authors: Sarem A.M. , Hawthorne R.G. 
Published: March 2010

Summary
A comparison of the heat-carrying capacity of hot water and steam indicatesthat hot water can impart considerably more heat to a formation than does steamat relatively low pressures. This results from the greater density of hot waterand its corresponding greater mass flow rate at a given injection pressure. Athigher pressures, this advantage of hot water becomes smaller, and itdisappears completely at the critical pressure of water.
The relative heat-carrying capacities of hot water and steam are influencedby the presence of residual oil in the formation. Greater oil saturations leadto lower heat-carrying capacities of hot water relative to steam. Thesedifferences are a reflection of differences in relative permeabilities of theflowing fluids.
The work reported here is considered to be preliminary in nature; severalbasic simplifying assumptions were used in it. Under conditions other thanthose assumed, the relative effectiveness of hot water and steam could besomewhat different from that reported here.

Introduction
When heat is imparted to a formation by hot water or steam injection, theoil recovery is increased due to thermal expansion of oil, reduction in oilviscosity and, in the case of steam drive, steam distillation of the crude (1).The degree to which oil recovery is increased is affected particularlyby the temperature dependence of the oil viscosity. In many cases, thereservoir oil viscosity can be reduced several hundred-fold by hot water orsteam heating to drastically increase the oil mobility. Figures 1 and2 show the relationship between temperature and viscosity for steam andwater (2). Note that water viscosity decreases with increasing temperature, butthat the steam viscosity increases with increasing temperature at pressuresbelow 1000 psi.
When a reservoir has been selected for heal treatment, it is necessary todetermine the most economical means of transferring heat into it. At firstglance, steam may seem to be a better heat carrier than hot water because itsheat content per unit mass is higher than that of water at the sametemperature.
Waterflood Behaviour of the Low-Gravity Wainwright Pool
Authors: Pawelek J. , Chorney M. 
Published: March 2010

Abstract
This paper outlines the development and performance of the Wainwright fieldin east-central Alberta, where the Wainwright sand produces 20–22-gravity oilfrom a depth of approximately 2,100 feet. The field was the first heavy oilpool in Alberta in which pressure maintenance by waterflooding was undertaken.Although pressure maintenance has been in progress for only three years, theperformance during this period is indicative of the project's success.
To forestall the adverse effects of rapid pressure decline and increasinggas-oil ratios in this solution gas drive reservoir unitization as aprerequisite to full-scale pressure maintenance was instituted. The field wasunitized as five separate units, with pressure maintenance conducted by two operators.
To the end of 1965, the cumulative oil production from the field wasapproximately 8,600,000 barrels. In December, 1965, oil production was 4,560barrels per day, with pressure maintenance accounting for approximately 70 percent of this. The ultimate recovery (primary plus waterflood) for the field hasbeen estimated at 31,300,000 barrels, which is more than double the recoveryanticipated by natural depletion.

Introduction
The Wainwright Sand reservoir is located on the southwestern flank of theheavy oil region of east-central Alberta. This is shown in Figure 1. Thefield was the first heavy oil pool in Alberta in which pressure maintenance bywaterflooding was undertaken. The reservoir was developed on 20-acre spacing, and the unitized areas include 202 producing wells. Reservoir characteristicsare included in Table I.
The reservoir has a gas cap and an aquifer. During primary depletion, itproduced principally as a solution gas drive reservoir with some gas capexpansion. This was evidenced by rapidly declining reservoir pressures andincreasing gas-oil ratios. Although some water was produced from down-dip wellsalong the southwest rim of the present producing limits, and there was anoticeable encroachment of water before unitized operations began, there was noappreciable recovery resulting from the water influx. Early in 1959, it wasobvious that the natural energy of the reservoir was going to produce only asmall fraction of the original oil-in-place.
Cementing Practices for Thermal Wells
Authors: Pollock R.W. , Beecroft W.H. , Carter L.G. 
Published: March 2010

Abstract
The introduction of steam as a means of stimulation for oil production haspresented many problems in oil well completions. Some of the difficultiesexperienced have been casing failures, pipe growth, cement failure and cementbond breakdown. Data are presented on cementing compositions and casingcementing techniques which may help build a sound steam injection well or onewhich can withstand the stresses and strains of intermittent steam injectionand production.

Introduction
Production of low-gravity, high-viscosity crude oil has been increased inrecent years by downhole electric heaters, in-situ combustion and steamstimulation (1). Of these methods, steam stimulation appears to be the mostpromising and is being used by many producers in the oil fields of Western Canada. Steam injection, by either of two systems, has become a complexproblem. The displacement or flood technique is considered to be lesstroublesome once the field has been prepared for it, but the necessary flowlines and permanent steam generating equipment makes the initial expense veryhigh. Most of the Canadian producers have utilized the second steam stimulationtechnique, that of intermittent steam injection with portable equipment - or, as it is more commonly called, "Huff and Puff." Although this second approachis less costly than the use of the permanent generating station, most of theproblems inherent with steam stimulation still exist. The most common problemsencountered are those of casing failure and/or cement failure. As long as steaminjection temperatures remain below 400°F, these problems seem to be at aminimum; however, as injection pressure increase, with the correspondingincrease in temperature, the quality of the casing, cement and cement placementbecome important factors in the success or failure of the treatment. Most ofthe Huff and Puff projects in Canada to date have been in the temperature rangeof 550° to 620°F (1,200 to 1,800 psi), although equipment is available to raisethese conditions to 670°F and 2,500 psi, respectively. Many treating failureshave been reported at the lower treating levels and many more failures areexpected to occur when the equipment is utilized to the maximum extent.
Downhole Fluids Accurately Sampled with New Wireline Tool
Authors: Kisling J.W. , Greer Larry P. 
Published: March 2010

Abstract
A new sampler, which is run on solid wireline, collects downhole samples offluid under closely controlled conditions. The sample can be used for PVTstudies to determine the physical and chemical properties of reservoirfluids.
The tool has very unusual design features that ensure that the propertiesand the volume of fluids and gases at the point of sampling are not altered inany way during the collection process. The integrity of this tool has beenproven by excellent results in field use.

Introduction
The object of bottom-hole sampling is to obtain a quantity of oil and gaswhich can be used to determine the physical and chemical properties of thefluids contained in the underground reservoir. These properties are, in turn, used to predict the production performance of the formation and also to determine the oil and gas reserves.
Basically, this process expands a very small quantity of fluid to manymillions of times its original size. Any discrepancies that exist in theoriginal sampling process will be magnified accordingly when the final resultsare calculated. This establishes the real need for a bottom-hole samplingdevice that collects and preserves a true sample of thesubsurface fluid.
The accuracy and integrity of the sample determine how valid the predictionscan be for the production performance of the well. The efficiency over theproducing life of the well will, in many cases, be dependent on the sepredictions and can drastically affect the total recovery to be achieved. Thesame qualities of accuracy and integrity of the sample will also determine the accuracy of the calculations of total reserves.