bluuebunny/crossref_metadata_2025_split huggingface dataset:
Water Analysis Data: Interpretation and Applications
Authors: Noad D.F. 
Published: March 2010

Abstract
The value of water analysis data in petroleum exploration and production iswidely recognized. Water analyses have proven useful in water productionproblems, in the correlation of stratigraphic units and of the aquifers withinthese units, and in the study of the movement of subsurface waters.
A large volume of water analysis data is available for the Western Canada Sedimentary Basin. Maximum benefits may be derived from these data through thecareful selection of analyses that represent most accurately the chemicalcomposition of the subsurface waters.
Various graphical methods have been devised for presenting the chemicalanalysis of a water. Graphical diagrams are particularly useful in comparingwater analyses.
Isoconcentration maps provide information essential for the study of thechemical and physical behaviour of formation waters. Furthermore, these mapsprovide information that can be converted readily to water resistivitydata.
Studies of the chemistry of formation waters, carried out in conjunctionwith studies of the geologic framework wherein the waters reside, can be mosteffective in the solution of local and regional problems.

Introduction
Subsurface water is a generally unwanted commodity found during the searchfor, and exploitation of, oil and gas reserves. Because subsurface water oftencontains a large amount of dissolved salts, it is unsuitable for domesticpurposes. By virtue of the dissolved salts and of certain gases held insolution, this water is a powerful chemical agent capable of corroding themetal in well equipment. Yet the very presence of these salts and gases makeswater analysis useful in certain exploration and production problems.
In addition to discussing the interpretation and applications of wateranalysis data, this paper discusses sampling procedure and analyticaltechniques. Proper campling and analytical methods are requisites to obtainingmaximum information on subsurface waters. This means ensuring that the samplesclosely represent the formation waters and that the chemical analyses provideadequate data for both present and future requirements.
Summary of a Report on Gas Flow Measurement
Authors: - - 
Published: March 2010

A study group was formed in February, 1961 by the CIM-AIME, Edmonton Section, to consider gas measurement problems encountered by the oil and gasproduction industry in Alberta. The prime purpose of the group was toco-ordinate the efforts of all those working on the problem and to provide aforum for the exchange of opinions, ideas and field results.
Sixteen organizations were represented at the inaugural meeting. Theseorganizations included oil and gas producers, gas transmission and gas utilityoperators, the University of Alberta and the Oil and Gas ConservationBoard.
The objectives of the group were:To review all methods of gas flow measurement suitable for use in the oiland gas industry.To evaluate the instruments employing these methods.To determine who has tested and/or accepted these instruments.To determine the accuracy and dependability of these instruments underspecified conditions.To determine the relative economies of the use of these instruments.To draw up a list of criteria which could be used for determining thesuitability of methods and instruments for gas flow measurement.
To achieve these objectives, four committees were formed to investigate thefollowing:Orifice metersPositive displacement metersMass flow metersOther methods of gas flow measurement.
The material prepared by these committees forms the basis of thisreport.
After a general introduction to the basic theory and principles of gasmeasurement, the report details all of the methods which may be applied to gasmeasurement. There are twenty-six different methods considered under thefollowing six general headings:Differential head metersVariable area metersVelocity flow metersMass flow metersPositive displacement metersMiscellaneous meters
Well-Bore Notching and Hydraulic Fracturing
Authors: Strain H.J. 
Published: March 2010

Abstract
Several advanced procedures for planning hydraulic fracturing treatmentswere introduced by research engineers during 1957 and 1958. Fracturing with thesingle-plane entry technique was one promising new concept. With this techniquethe well-bore is prepared at a selected point using a hydraulic or a mechanicalnotching tool. The well is then fractured with a treatment designed to generatea single, large-areal-extent fracture. A partial monolayer of large-sizepropping agent is distributed in the fracture to give high-flow capacity afterthe treatment. An experimental program was conducted in the Pincher Creek, Steelman and Pembina fields during 1959 and 1960 to evaluate single-plane-entryfracturing. It was found that the technique could not be indiscriminantlyapplied to every reservoir. Interference from natural vertical fracture systemswas a problem. However, when reservoir conditions were favorable, the resultsindicated that wells fractured with the single- plane entry technique havehigher and more sustained productivity than those fractured by conventionalmethods.

Introduction
Significant technological advances in the science of hydraulic fracturingwere made by research engineers during 1957 and 1958. These were received withconsiderable interest by the Canadian oil and gas industry. In particular, theconcept of a single, high-flow-capacity fracture held promise for many areas.An experimental program was carried out by The British American Oil Company Limited during 1959 and 1960 to evaluate some of the new fracturing theories.Fracturing with the single-plane entry technique was first attempted in Canadaat a gas well in the Pincher Creek field.
Another proving ground for this type of fracturing were poor-productivitywells along the north side of the Steelman field. Rapid decline in productionrate after normal acid completion treatment was characteristic of wells in thisarea. Conventional sandfracturing had been tried with no success. In an effortto overcome the problem and work out a superior completion method, single-plane-entry fracturing treatments were performed on nine edge wellsduring the latter part of 1959 and in early 1960. An abrasive jetting tool anda mechanical under-reamer were evaluated as a means of notching the well-bore.Partial-monolayer and multilayer fracturing treatments were tried inconjunction with the single entry. Production data from these nine experimentalwells and from offsetting conventionally completed wells are compared toevaluate the usefulness of the single-plane entry technique and thepartial-monolayer propping theory.
Allowables and Allowances
Authors: Lee C.S. 
Published: March 2010

Introduction
The problem of proration to market demand has always been highlycontroversial. Because another hearing is to be held on November 5th, 1963 -the last one of importance was in 1961 - this review is an attempt to compile arepresentative bibliography and to present the issues for debate which havearisen in the past and those which can be anticipated in the future. From thispoint of view, it is hoped that it will provide some background and avoid someduplication of research for those who propose to take an interest in thesecoming hearings. Whether from the standpoint of equity or of economics orfurther development and investment, these hearings will be vital to the futureof the oil industry in Alberta. No recent hearing has been more important.
This paper does notrepresent the views of any group and does notpurport to offer any solution. The writer reserves the right to advocate orjoin in advocating such solutions as may be considered appropriate at the timeof the hearing.
Historical
The competence and jurisdiction of the Oil and Gas Conservation Board of theGovernment of the Province of Alberta in the matter of proration of crude oilto market demand does not call for any lengthy discussion. It is contained inSection 36 (1) of the Oil and Gas Conservation Act, which, amongst otherthings, states that each owner should have an opportunity of obtaining his justand equitable share of the production of any pool.
Until 1949 the Oil and Gas Conservation Board set certain standards, in anattempt to preserve good engineering practices, of so-called "maximumproduction" (2). However, following the discovery of Redwater, the provincialproducing potential on this "maximum production" basis grew to a figure which, by 1950, exceeded the available demand by a wide margin. Nearly all the demandat that time was in Alberta.
How to Keep Tubing Sealed in Packers
Authors: Logan J.L. 
Published: March 2010

Abstract
In many oil, gas, and injection wells. a string of tubing, sealed at itslower end in a packer, is used to isolate tubing pressures and fluids from thecasing. In multiple completions, two or more tubing strings are used to isolatezones. This paper presents a means of determining the best way to initiallyland the tubing in the packer to compensate for future anticipated wellconditions.
The equations in this paper were developed in a previous publication andhave been successfully applied to over fifty critical wells in the UnitedStates, Canada, and Europe. Many of these were deep, high-pressure, high-temperature, high-cost wells in which it was imperative that atubing-to-packer seal be maintained during all completion, remedial. andproducing operations. In some of these wells, it was important to keep thetubing as straight as possible to facilitate future wire line work.
The conditions of these wells have been grouped and tabulated so the readercan see some of the practical applications of the paper.

Introduction
The bottom of a string of unanchored tubing in a rod-pumped well moves up onthe upstroke and down on the downstroke. In addition, the tubing graduallyelongates until the well reaches pumping equilibrium. Disregardingrod-to-tubing friction, vertical movement is caused by pressure and temperaturechanges acting on the entire tubing string. Knowing tubing and casing size, initial and final fluid densities and levels, and initial and final tubingtemperature, it is possible to calculate the extent of these verticalmovements.
Rod-pumped wells are generally familiar to the reader and are mentioned herebecause the freely hanging tubing string reacts in exactly the same manner tochanges in well conditions as does a string of tubing sealed, at its lower end, in a packer which permits free seal movement. A packer, however, may be setmuch deeper than a pump, and not only is a longer string of tubing exposed tothese changes but the changes may also be much more severe. Consequently, theamount of vertical movement is usually much greater.
Geochemical Studies of Natural Gas Part I. Hydrocarbons in Western Canadian Natural Gases
Authors: Hitchon Brian 
Published: March 2010

Abstract
Natural gases in Western Canada are found in sediments ranging in age fromCambrian to Tertiary. The hydrocarbons in these gases are described andevaluated in terms of their geochemistry, origin, migration andaccumulation.
Hydrocarbons are the chief components in the majority of the nearly 3,000analyses of natural gases from Western Canada. Most gases contain more than 90per cent hydrocarbons, but as little as 0.26 per cent is present in some. Thepreferred order of abundance of the individual hydrocarbons is methane &gt;ethane &gt; propane &gt;n- butane &gt;isobutene &gt;isopentane &gt; n-pentane &gt; hexanes &gt; heptanes. A decreasingn-butane:isobutane ratio is accompanied by an approach to unity of theisopentane :n-pentane ratio. Study of the C4 andC5 isomers indicates that no reservoirs are in thermodynamicequilibrium. Variations in the C4 and C5isomer ratiosare attributed to catalysis by the sediments.
Methane probably originates due to direct synthesis by bacteria, although itis also a by-product of biochemical reactions that are able to generatehydrocarbons with from two to ten carbon atoms. These reactions includelow-temperature decarboxylation and reductive deamination of amino acids anddecarboxylation of fatty acids. The part played by bacteria in these reactionsis probably important, although the mechanism is not known with any degree ofcertainty.
Natural gases with relatively low contents of methane and high contents ofheavy hydrocarbons are found in sediments deposited in basinal environments. Insediments deposited in shelf environments the natural gases have highercontents of methane and lower contents of the heavy hydrocarbons. Forpre-Cretaceous strata in Western Canada, the depositional basins approximatelycoincide with the present structural basin, and fluid flow is updip. ForCretaceous strata, sediments in the structural basin contain natural gases withrelatively low contents of methane except where modification due to downdipfluid-flow has occurred. Possible mechanisms inducing modification of theregional variations include undersaturation of the formation water with naturalgas at present reservoir temperatures and pressures, and variations in thesolubilities of the hydrocarbons due to changes in flow direction and movementinto regions with formation waters of different salinites.
A Reservoir Study of the Sturgeon Lake South D-3 Pool
Authors: McKibbon J.H. , Paxman D.S. , Havlena D. 
Published: March 2010

Abstract
This study illustrates the use of the expanded material balance to determinethe volume of oil originally in place and to define the aquifer system.
The expanded material balance, which incorporates an unsteady-state waterinflux term, contains two explicit and several implicit unknowns. The solutionof such a material balance is accomplished by algebraically rearranging theterms to define the equation of a straight line. Such a straight-line conceptis then used to define the various unknowns. Both linear and radial aquiferconfigurations are considered and the acceptability of the results arestatistically tested.
Due to the installation and subsequent extension of a gas gathering systemin the field, there have been two major changes in the field separatorpressure. These variations in separator pressure are accounted for in thecalculations.
The study concludes that the performance of the Sturgeon Lake South D-3pool, to date, has been consistent with a radial aquifer system which has notyet felt boundary effects. The volume of oil originally in place as determinedin this paper is in excellent agreement with the volumetric estimate.

Introduction
The Sturgeon Lake South field is situated some 160 miles northwest of theCity of Edmonton. Alberta. The D-3 pool the only productive horizon of anyconsequence in the field, was discovered in early 1953 with the drilling of thewell Amerada HB Union Crown "R" 5–19 (Lsd 5–19–69–22 W5). While sporadicdrilling in the field is continuing, development was substantially completed bythe end of 1957 when some 100 producing oil wells had been completed. There arecurrently 112 wells capable of oil production from this reservoir.
Several calculations have been performed in the past to establish avolumetric estimate of the original oil in place; however, due to limited wellcontrol in the southwestern part of the pool (see the attachedstructure-isopach map of Figure1), and a controversy concerning theconnate water saturation, the volumetric estimates for this reservoir haveshown a wide variation in values. These differences in the volumetric estimatesprompted the present detailed investigation.
Geochemical Studies of Natural Gas Part II. Acid Gases in Western Canadian Natural Gases
Authors: Hitchon Brian 
Published: March 2010

Abstract
Hydrogen sulphide is of interest as an economic source of sulphur, fromconsideration of corrosion problems, as a health hazard, and as a geochemicalguide. It forms an essential link in the cycle of sulphur, it occurs widely innature, and, with carbon dioxide, is a byproduct of the bacterial reduction ofsulphates. The close association with low contents of dissolved sulphate information waters, and with the presence of sulphate-reducing bacteria in someoil-field waters, is consistent with a biogenic origin for these two componentsin the bulk of natural gases. The few exceptions (natural gases with commonlyless than five per cent hydrocarbons, no hydrogen sulphide and consistingpredominantly of carbon dioxide) probably owe their origin to metamorphism ofbituminous carbonates.
The contents of both hydrogen sulphide and carbon dioxide in natural gasesfrom Western Canada vary regionally, although the trend patterns are not alwayssimilar. In some stratigraphic units hydrogen sulphide probably has beenremoved from the aqueous system through reaction with iron in solution and thesubsequent precipitation of pyrite. In other units, oxidation of crude oils mayhave relatively increased the content of carbon dioxide in the natural gases.In spite of the probable operation of these phenomena, the major factorcontrolling the content of hydrogen sulphide and carbon dioxide in naturalgases is the environment of deposition of the sediments, a view that is inaccord with a biogenic origin for both acid gases.

Introduction
This paper is the second of a series concerned with the geochemistry ofnatural gas in Western Canada. It discusses the acid gases hydrogen sulphideand carbon dioxide. The first paper dealt with the hydrocarbons and the thirdpart will treat the inert gases.
Developments in Oil and Natural Gas Production Southwestern Ontario
Authors: Oakley K.A. 
Published: March 2010

Abstract
Southwestern Ontario's oil and gas industry has had its fluctuations overthe past 100 years. At present oil production is in an extended maximum cycleand gas production is trending downward from a maximum cycle. Trends forecastinclude secondary-recovery and pressure-maintenance projects in Devonian andSilurian reservoirs, declining gas production through depletion of pinnaclereefs, and a stepped-up Cambrian exploration programme to find more fields likeClearville and Gobles.

Introduction
The history of the oil and gas industry in southwestern Ontario stretchesback over more than 100 years. During this time, the production of both oil andgas has passed through several very severe cycles, until today oil productionis enjoying an extended maximum cycle while gas production appears to betrending downward from a maximum cycle. This paper presents a brief look at thepast, a review of present conditions and a forecast of possible futuretrends.
It was in 1857 that James Miller Williams found petroleum in quantitiessufficient to warrant setting up refining equipment at Ennis-killen. Thecommercial production of oil has been going on ever since. Gas production datesback to the discovery of the Kingsville, Haldimand and Welland fields in thelate 1880's. After all this time - 100 years since the first crude was producedand 75 years since the first gas- one might well ask what there couldbe left to say about such a long-established industry that would bear on thesituation today. Nevertheless, a brief survey of developments in southwesternOntario since the beginning may help to place recent events in their properperspective.
Athabasca's Place in the Future
Authors: Spragins F.K. 
Published: March 2010

Abstract
A general survey of Western Canada's oil industry from 1778 to the presentsuggests that development of the Athabasca oil sands will play a prominent partin sustaining Alberta's key position in the national energy picture.
The First Oil Men
Oil development in Western Canada has had a long and sometimes weirdhistory. Many events from the past are now all but forgotten, but there areothers which stand out as milestones in our struggle for world recognition as asignificant oil-producing area. Although the experiences and happenings thateach of us remembers may vary, every one of them has its place in ourindustry's colourful background.
Looking back in time, we must recognize that Canada's first oil men were theIndians who lived along the Athabasca river in 1778. Even then, nearly twohundred years ago, they realized the importance of this product that was allaround them, having found that a mixture of Athabasca bitumen and spruce-treegum made a fine compound for waterproofing canoes. History does not relatePeter Pond's experiences with Athabasca oil but, by the time AlexanderMackenzie relieved him in 1787, the oil men were ready for business. For asuitable amount of whisky, the Indian chief would provide Mackenzie with thebitumen he needed to caulk his canoes. I have often wondered how the Scotsmanreacted when he found the stuff he had been forced to buy was literally runningout of the banks in many places for over 100 miles along the Athabasca river!These spots he later described as "fountains of bitumen."
Early Beginnings
Despite this early "commercialization" however, Athabasca oil remainedrelatively unheeded until recent years. Instead, other major fields in manyareas were discovered and developed until Western Canada became established asone of the leading oil-and-gas-producing areas of the world. Let us take a lookat how this came about.
A Practical Approach to Gas Deliverability Predictions with the Use of an Electronic Digital Computer
Authors: Chernoff G.M. 
Published: March 2010

Abstract
This paper presents a method of estimating the physical deliverability ofgas at the wellhead from depletion-type gas reservoirs, prior and subsequent tothe years of declining production. A prediction programme suitable for amedium-sized digital computer is given. It utilizes measured wellhead pressuredeliverability and absolute open flow potential curves for a field-averagewell. The predictions show the length of time a field is capable of deliveringa specified constant daily volume of gas. In addition, for each predictionperiod, the average reservoir and wellhead pressures, the average maximumproduction capacity, the QMax as determined by the Alberta Oil and GasConservation Board formula, and the cumulative gas volumes produced arecalculated. The programme also takes into account field compression and/or thedrilling of additional wells when required.

Introduction
Reliable gas deliverability predictions are essential for economic forecastsof gas field performance. The calculation basically involves an adaption of thefamiliar equation in U.S.B.M. Monograph7, relating flow rate toreservoir pressure. The equation only indicates a well's capacity to producegas at the reservoir sand-face. In actual practice, it is desirable to know thegas volumes a well is capable of delivering against a back pressure oftransmission lines, processing plants and field gathering lines. When the openflow equation is used for pipeline or wellhead deliverability calculations, itis necessary to calculate a relationship of Q versus flowing sand-facepressures for a constant-flowing wellhead pressure. As wellhead pressures areusually measured during back-pressure tests, these are used directly inplotting a wellhead deliverability curve, as described by Crawford (1).
For maximum reliability, the predictions for any field frequently must berevised as additional information and production history become available. Toperform the calculations by hand is an arduous task requiring considerable timespent on routine work. A medium-sized electronic computer is ideally suited forthis application, and, after the programme is written, long-rangedeliverability forecasts at various rates may be made in a matter ofminutes.