bluuebunny/crossref_metadata_2025_split huggingface dataset:
Depletion, Gas Conservation, Cycling and Pressure Maintenance Performance - Harmattan East Rundle Pool, Alberta
Authors: Fehlberg E.L. , Nielsen W.M.R. , Taylor R.L. 
Published: March 2010

Abstract
The Harmattan East Rundle oil and associated gas-cap accumulation iscontained in a stratigraphic trap limited downdip on the oil leg by anerosional channel and updip in the gas cap by truncation of the Turner Valleyformation of the Rundle group. A total of 178 million barrels of stock tank oiland 1,100 Bcf of associated gas-cap gas were estimated to be originally inplace. The gas cap is shut-in pending reasonable depletion of the oil column. Agas-cap cycling scheme was engineered to increase and accelerate recovery ofgas-cap liquids and to partially maintain oil-column pressure during cycling. Anumerical solution to the differential equation for two-dimensional horizontalsteady-state flow was used to determine the location, production and injectionrates for each well in the cycling scheme. The expanded material balance, unsteady-state flow and gas displacement equations were combined for predictingthe performance of this combination-drive reservoir.

Introduction
The Harmattan East reservoir, discovered in 1956, is located approximately50 miles north-northwest of the city of Calgary (Figure1), in theProvince of Alberta. Oil production is obtained from the Mississippian TurnerValley formation at an average depth of 8,500 feet. The Turner Valley erosionalremnant is underlain by impermeable shales and sandstones of Jurassic andCretaceous age. Reservoir development within this formation occurs in zones ofporous dolomite with associated beds of dense limestone.
The east, south and west productive limits of the field have been fairlywell established. The northern limit, however, has yet to be defined.Development of the oil column is nearly complete and, as of January 1, 1963, there were ninety producing oil wells on 80-acre spacing. Gas-cap developmenthas resulted in sixteen gas-condensate wells. In December of 1961, a scheme forconserving casinghead gas was initiated.
Use of Direct Electrical Current for Increasing the Flow Rate of Reservoir Fluids During Petroleum Recovery
Authors: Amba S.A. , Chilingar G.V. , Beeson C.M. 
Published: March 2010

Abstract
Synthetic cores containing various percentages of different clay mineralswere flooded with water which contained different types of salts in variedamounts, and the flow rate was measured during the application of directelectrical current at varying current density. Kerosene also was used as theflowing fluid, and some chemical additives, such as sodium acid pyrophosphate, were tested in conjunction with the application of electrical current.
The experimental results indicated that the increase in the flow rate ofliquids was due not only to the electroosmotic effect but also to some changesin the pore structure. These changes in the pore configuration took placeduring the electrochemical treatment and generally resulted in higher finalhydrodynamic permeability. As a result of the physicochemical changes in theclay properties, the tendency of the clay to swell and absorb water wasmarkedly decreased. In these systems, the electrical or electrochemicaltreatment appeared to be an irreversible process. The extent to which theseelectrochemical changes were produced depended in general on the amount ofcurrent passed, the magnitude of potential gradient imposed, the amount andtype of clay minerals present, and the type and concentration of electrolyticsolution used.

Introduction
The increasing importance of either primary or secondary recovery of oilfrom tight, clayey formations, and the difficulties encountered in suchrecovery due to clay swelling, suggested the possibility of utilizing directelectrical current to augment reservoir energy. The effective permeability tooil, especially around the borehole, greatly affects the productivity of an oilzone. A decrease in the relative oil permeability around the well can be causedby infiltration of the mud cake filtrate. This suggested the use ofelectrochemical treatment as a method for well stimulation.
LPG - A New Element in Canadian Energy
Authors: Getgood John 
Published: March 2010

It is a genuine pleasure to be here this evening and to participate in thisseries of talks sponsored by the Canadian Institute of Mining and Metallurgy.As one who has worked all his business life in the petroleum industry, Iespecially appreciate an opportunity to associate with this highly respectedorganization. As many of you know, we oilmen were for a long time regarded asrank-outsiders to the serious profession of mining. Some of the moreconservative, hard-rock members of this Institute looked upon us as meredabblers in the business of exploring the earth's crust and, I suppose, theythought none of us had any more claim to being mining men than a gravedigger ora fisherman who goes spading for worms in his back yard.
Fortunately, here in Alberta, that antiquated idea was buried some years agoand a special petroleum section of the Institute was formed. The record provesthat it has been a valuable association for all concerned. Our mutual interestsare clearly shown in this series of talks in which uranium, coal, natural gasand oil men are getting together to discuss their common roles as suppliers ofenergy to the Canadian Nation.
As I stand here tonight, with the uncomfortable chore of trying to make aspeech, I just wonder if the Institute did not have an ulterior motive inadmitting oilmen to membership. Perhaps they had heard that story about theloud-mouthed young recruit who showed up at the army training camp. Thesergeant listened as long as he could stand it, then turned to the corporal andsaid: "What makes this kid talk so much?" "He can't help it," said thecorporal, "his mother was a woman and his father was an oilman."
An Investigation Concerning the Material Balance Equation Part One: The Linear Form of the Equation
Authors: Nader W. 
Published: March 2010

Abstract
The Material Balance Method, as applied to petroleum reservoirs, isinvestigated in this paper. Using less restrictive assumptions than are usuallyemployed, a Material Balance Equation is derived which is linearin theunknown reservoir parameters - initial oil, free gas, interstitial water androck material in place, and water encroachment factor. Both systematic andrandom errors are discussed. The elimination of random errors by the use of the Principle of Least Squares and the detection of systematic errors, althoughonly mentioned at this time, will be shown in detail in the second part of thestudy.

Introduction
The solution of specific problems in petroleum engineering often dependsupon the successful application of ideas, methods, techniques and tools, originally developed in other branches of engineering or the sciences.Consequently, every year, new ideas are introduced into petroleum engineeringfrom other disciplines. Recently, for instance, the expanding usage ofelectronic computer devices has drawn attention to the mathematical methods of Linear Algebra. Naturally, it is now realized that the application of thismethod need not be restricted to computer usage.
In general, the introduction of a new technique will necessitate areappraisal of present methods. This action may result in some modification inthe approach to and the formulation of certain problems. Such alterations mayormay not require modifications of the original principles involved.
This investigation presents the case of the ‘Material Balance Principle’ andthe ‘Material Balance Equation’ in view of the above-mentioned Linear Algebra.The original form of the Equation and several of its modifications suffer fromtheir non-linear character, which severely restricts their usefulness, whenconsidering modern requirements. Thus, the application of the Principle of Least Squares - another one of the more recently acquired tools - is found tobe an awkward task. For example, the use of the Principle may lead to atrial-and-error search for the ‘best’ numerical values of certain reservoirparameters.
Radial Motion of a Surface Between Fluids Within a Porous Medium
Authors: Perrine R.L. , Gay G.M. 
Published: March 2010

Abstract
Economic use of solvent flooding for secondary recovery of oil requires thelimitation of miscible solvent. In turn, solvent requirements depend onspreading from dispersion; reservoir heterogeneity, viscous fingering, and thetendency for low-density solvent to rise above oil, or to override.
This paper considers miscible displacement outward from a central well in alarge cylindrical system. Under appropriate conditions, initial viscous fingersmay become damped out as they are spread in several directions by gravity anddispersion. Mathematically, displacement behaviour is represented by theradially outward motion of a free surface, representing the "interface" betweenfluids, from injection well toward producing wells. The equivalent linearproblem has been reported by several authors, but extrapolation to thecylindrical case is not justified.
An approximate equation of motion for the free surface is deduced. Solutionsof the nonlinear equation are obtained by finite difference methods. For thelimiting case of a small density difference, just enough to cause fluidsegregation, a simple analytical solution describes the motion of the endpoints of the surface. Comparison with numerical results shows that the simplesolution provides a useful measure of the anticipated overrideforessentially all practical conditions.

Introduction
The injection of a miscible solvent to displace oil from a reservoir is apotentially valuable secondary recovery method. Field application has shownvarying degrees of success, however. Economic use of the process places a limiton the quantity of miscible solvent that may be used. In turn, the solventrequirement depends on the spreading initiated by viscous fingering (1), dispersion (2), pattern effects which cause incomplete sweepout, reservoirheterogeneity which leads to rapid breakthrough in portions of the reservoir,an d on the tendency for the solvent to override the oil. The latter is causedby a combination of density and viscosity differences.
Formation Evaluation in Heavy Oil Sands
Authors: Brown James S. 
Published: March 2010

Abstract
"Formation evaluation" comprises correlation, reservoir detection andreservoir evaluation. In the Chauvin, Wainwright and Lloydminster areas, theprincipal heavy oil reservoir is the Sparky sand. The oil sand pools are surrounded by halos or "channels" of shale. Correlation is more difficult inthe Lloydminster area than in the Wainwright area or the Chauvin area becausethe sand distribution is more complex. Reservoir detection is more difficult at Wainwright and Chauvin because the oil sands are thin and apparent resistivities are low; at Lloydminster, the oil sands are thick and apparent resistivities are high. At Wainwright and Chauvin, a resistivity log, aporosity log and often a drill stem test are necessary for a decision to set pipe; at Lloydminster, all that is required is an electrical log. Productivity varies considerably from pool to pool, probably because of changes in sand permeability and oil viscosity. As these changes cannot be detected by the electrical log prior to setting pipe, the present practice is to determine productivity by production testing after setting, pipe. Transmissibility(kh)/u, as derived from drill stem test data, may provide a means of estimating productivity prior to setting pipe.

Introduction
The techniques used for formation evaluation vary from area to area, as each area has problems which are peculiar to it. The purpose of this paper is to discuss some of the problems peculiar to the heavy oil reservoirs of the Lloydminster, Chauvin and Wainwright areas, and to mention certain techniques which provide the necessary data simply and economically. In the following, the Lloydminster area will be discussed first; this will be followed by adiscussion of the Wainwright and Chauvin areas. The geology of each area willbe commented on, but only insofar as it bears on the problem of correlation andreservoir identification.
Design of Hot Water Tracer Systems to Prevent Hydrate Formation in Gas Gathering Lines
Authors: Lukacs J. , Leith H.E. , Nader W. 
Published: March 2010

Abstract
This paper is a follow-up to a similar paper, presented at the C.I.M.Petroleum and Natural Gas Division's Annual Technical Meeting in Calgary in1962, on the method for transporting wet natural gases utilizing hot watertracing. In this paper, this new approach in gas gathering is examined in lightof two years' operating history, with special emphasis on the heat transferbetween pipes and the soil. Solutions for the steady-rate heat transfer fromsingle pipes and parallel buried pipes are presented in the paper.
Practical soil conductivities were calculated, using these equations, fromsix months of test data. It was found that the over-all thermal conductivity inthe Wildcat Hills field varies only between 0.4 and 0.65 Btu/(hr.) (sq. ft.)(°F/ft.), in spite of the wide variety of soil types.
Based on the experience gained from the operation of the Wildcat Hillstracer system, and from heat transfer studies, a suggested design procedure ispresented in the paper.

Introduction
Natural gases form hydrates in the presence of free water at temperatures higher than the freezing point of water. The temperature of hydrate formationis a function of the pressure and the composition of the gas. One way to prevent hydrate formation is to maintain the gas temperature above the hydrate formation temperature. A tracer system can be defined as a means of hydratecontrol by heating gas gathering lines with hot water lines. The application ofthis method to gas gathering systems was proposed by Mr. T. Nitescu, president of Canadian Fina Oil Limited. The basic principle of the tracer system is thatby maintaining the soil around the gas pipe at or above the temperature of thegas, there would be no heat loss from the gas to the soil. The soil around the gas line is heated by a hot water line or, as generally referred to in this paper, the "tracer line."
Basic Contrasts Underlying Petroleum Land Policies of the United States and Canada
Authors: Thompson A.R. 
Published: March 2010

Abstract
The early policies and legislation under which petroleum was developed onthe "public domain" lands in the United States and on the "Dominion lands" in Canada are examined to reveal some important contrasts. The most importantcontrast is found in mineral reservation policies, which in Canada reservedmost petroleum lands for public ownership – first federal and then provincial. The author finds differing emphasis in these policies and legislation, which hecharacterizes as individualistic in the United States and paternalistic in Canada. The paternalistic emphasis in Canada has historical roots in indigenouspetroleum legislation uninfluenced by the free-miner tradition from the very beginning in Alberta; in the authoritarian nature of government in the Canadian West under the regime of the Hudson's Bay Company, and later of the Canadian Pacific Railway and the federal Department of the Interior; and, finally, in aconstitutional setting enabling a more pervasive public interest tocharacterize petroleum lands legislation in Canada.

Introduction
It is hardly necessary to remind an audience of petroleum geologists and engineers that the Crown-owned petroleum rights in Western Canada are of majorsignificance. However, it is well to set the stage for this paper by statingthat Crown-owned lands and minerals exceed one billion acres in Alberta, Manitoba and Saskatchewan and in the Northwest and Yukon Territories, includingthe Arctic Islands, that they encompass the Athabasca oil sands, andthat, from conventional oil fields, they account for more than two-thirds of Canada's petroleum reserves and production.
The purpose of this paper is to study the background of these publicly-owned lands and to compare this background with the history of the public domain lands in the United States for what light can be shed on modern-day developments.
I do not intend to review the history of the inception of the Crown-ownedlands in Western Canada. This subject has been dealt with by other speakers onother occasions, notably by Mr. Somerville, the deputy minister of Mines and Minerals. I shall merely refer to some highlights.
Application of Computer Technology to Reservoir Studies in Canada
Authors: Irby T.L. , Arps I.H. 
Published: March 2010

Abstract
Three-dimensional block models of petroleum reservoirs can be mathematicallyconstructed and solved by high-speed digital computers. Machine programs havebeen written which will solve a reservoir model consisting of more than 5,000 blocks. This permits the effect of areal variations of thickness, porosity and permeability to be studied in much more detail than was formerly possible. Themodels are particularly applicable in pressure maintenance and secondary recovery studies, but are also useful for optimizing well spacing during development operations.

Introduction
In the oil-producing areas of Canada, the use of mathematical model studies performed by high-speed computers is feasible for more major fields and wouldproduce more advantageous information than in any comparable oil-producing areaof the world today. This is primarily because the Canadian oil industry is ayoung one; most fields have been developed since the importance of applyingreservoir engineering principles to production was realized. Also, thedevelopment has taken place during a period when advanced technology permitted the acquisition of adequate data on reservoir and formation characteristics.That is, diamond coring and methods of regular and special core analysis were available, and modern logging methods, with logs which would give quantitative information, were offered. During the major development period, members of both industry and the Conservation Board recognized the need for obtaining sufficient reservoir data, not only from cores and logs but also from performance, so that well production tests, pressure surveys and build-up or drawdown data are usually available. Also, the importance of early pressure maintenance projects to obtain maximum recovery, and cooperation in the unitization of fields to obtain this end, has been well recognized.
Maximum use of the available data for reservoir performance studies and predictions can be made today through numerical models designed for modern computers. We have used these models successfully in a number of large fields, and their value has been proved.
Liquid Nitrogen Developments and Applications in Drilling and Completion Operations
Authors: Shouldice S.P. 
Published: March 2010

Abstract
Nitrogen is not a cure-all, but the results of field and laboratory workthat have evolved during recent years support its use as a valuable aid indrilling and completion operations. The advanced liquid nitrogen techniquespioneered in the Gulf Coast of the United States in 1959 have experiencedsignificant growth in the past four years. Such techniques are not confined tojust one or a few applications but have become intertwined with every aspect ofwell development and have made obsolete many oilfield practices previouslyemployed throughout North America. Liquid nitrogen, pumped at pressures of upto 10,000 psi, is forced through a gasifying heater and the colourless, odourless inert gas is injected into the well to perform a variety of valuable, safe and time-saving functions. These techniques have been field-proven inthousands of jobs and are supported by research results.
Industry has developed nitrogen procedures to:Provide uncontaminated drill stem test samples, reduce misruns and setpackers.Bring in wells without swabbing and its inherent hazards - day ornight.Enhance the benefits of stimulation treatments and force spent acid andfrac fluids out of the formation quickly and more efficiently, thus reducingwell bore damage and increasing productivity.Boost hydraulic perforating stream penetration up to 300 per cent, andsimplify "dry" gun perforating.Quickly droll mud weights to combat lost circulation while drilling andcementing.Combat paraffin and corrosion and increase inhibitor treatmenteffectiveness.Prevent downhole explosions when air drilling, and reduce formationcontamination by using nitrogen as a drilling fluid.

Introduction
Today, thanks to the missile age, the oil industry is served by liquidnitrogen units that are equipped with positive displacement "cryogenic" pumps.The cryogenic (super-cold) pumps were developed to handle fluids as cold as-350°F, which are common in the missile industry. With the introduction of thefirst liquid nitrogen unit in December, 1959, in Texas, and the use of thecryogenic pump, the versatility of nitrogen for oilfield uses has greatlyincreased.
Application of Advanced Well Treatment Knowledge
Authors: Hurst R.E. 
Published: March 2010

Abstract
Most well stimulation treatments involve the injection of some type ofliquid into subsurface formations. Rates of injection may be such that either amatrix treatment or fracture treatment will result. Improper application ofeither type of treatment may result in increased completion costs and damage toa well from the standpoint of ultimate recovery or future use as a storage orinjection well.
Well stimulation technology has advanced so rapidly during the past decadethat most production and engineering personnel have not had enough time toproperly analyze and apply all the new data, materials and techniques. Thispaper reviews new developments and shows how the various data may be collected, combined and applied for better treatment results and higher well profits.

Introduction
At some time in the producing life of most oil and gas wells, the need forstimulation arises. To make stimulation treatments more successful, a greatnumber of organizations and individuals have devoted large sums of money andtime to the development of improved engineering data materials and techniques.More technical information on well stimulation has been developed in the lastdecade than in the entire previous life of our industry. Because of this rapiddevelopment from many sources, most individuals have not had enough time toanalyze and apply much of this new data, and thus may not be receiving theavailable benefit. The purpose of this paper will be to show how, throughcollecting, combining and applying various data, the treatment of wells can bemore clearly understood and the results improved.
Stimulation by Injection
Most stimulation treatments in use today involve the injection of some typeof liquid into the formation. The stimulation effect of this injection dependslargely on what pattern the liquid follows in flowing from the well bore intothe formation.
If injection is started at a sufficiently low rate into a permeableformation and then increased, an injection- pressure profile can be drawn asshown in Figure 1.