bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Method of Predicting Availability of Natural Gas Based on Average Reservoir Performance
Authors: Davis Ralph E. , Meltzer Lee Hillard 
Published: April 2012

Introduction
During the past few years emphasis has been placed upon methods of estimating the future expectancy of gas production from natural gas fields. Before technical methods were applied, the production expectancy over future years was based upon the knowledge of gas well behavior, learned through long experience and embedded in the "know-how" of men long in the gas producing business. It is doubtful that a technical study of future expectancy of a gas field or a group of fields was ever prepared for the preliminary planning of a natural gas pipe line system built prior to about five years ago.
The decline in well production capacity was naturally recognized by all familiar with the business since its earliest beginnings more than 75 years ago. In 1953, the Bureau of Mines published Monograph Number 7, "Back-Pressure Data on Natural Gas Wells and Their Application to Production Practices," which gave to the industry the first technical analysis of the decline in production of individual gas wells. This method affords a means of estimating the future production in relation to decline in reservoir pressure.
The demand for technical determination of expectancy of future gas productivity from fields or a group of fields led technical men to the application of the knowledge of well behavior to the problems. The decline in a well's ability to produce as pressures declined could be estimated by the use of the curve known as the "back-pressure potential curve" as developed by the Bureau of Mines. A field containing few, or even numerous, wells could be analyzed on the basis of the sum of potentials of all wells.
In most studies of this nature, the problem is to estimate the rate of production that can be expected, not only from present wells but also, from wells that will in the future have to be drilled into the reservoir being studied. The "back-pressure potential" method requires that the following data be known or estimated:Proved gas reserves.Current shut-in pressures and rate at which shut-in pressures change with production.Back pressure potential data on wells in the source of supply.Ultimate number of wells which will supply gas, and their potential.Limitations on productivity such as line pressures against which the wells will produce, friction drop in the producing string, and so forth.
Volumetric Efficiency of Sucker Rod Pumps When Pumping Gas-Oil Mixtures
Authors: Connally C.A. , Sandberg C.R. , Stein N. 
Published: April 2012

Abstract
This paper describes the results of volumetric efficiency tests on oil, well pumps handling gas oil mixtures. The work was performed in a large scale, above ground unit wherein test conditions could be accurately controlled and measured.
The main variables studied were gas/oil ratio (including gas from solution and free gas mixed with oil), pump compression ratio, pump stroke length, pump speed, and clearance volume between the valves at their closest approach. Results are presented for two different pumps and for oils of two viscosities.
Relatively small amounts of gas entering the pump resulted in large decreases in volumetric efficiency. Under conditions where the pump was operating at reduced efficiency because of the presence of gas, it was found that variation in the clearance volume between. the standing and traveling valves had a considerable effect on pump efficiency level. This effect of the valve clearance volume was found to be significantly altered by the viscosity of the oil used in the tests. The effects on pump efficiency of the other variables studied were found to be relatively small over the range of conditions utilized.

Introduction
The production of oil by pumping is often hampered by low volumetric efficiency. A direct increase in lifting costs results from low volumetric efficiency. An indirect increase in lifting costs, probably greater than the direct increase, results from additional wear and tear on pumping equipment and from the down-time necessary for the repairs which can be traced to low-efficiency operation. Both increases in lifting costs tend to reduce economically recoverable oil.
A number of different factors can contribute to low pump efficiency. A known basic cause of low efficiency is the presence of free gas in the pumped fluid. Pump volumetric efficiency is calculated only on the basis of liquid pumped and because any free gas pumped is discounted, this volume of free gas would represent a loss of pump efficiency. However, gas also causes a reduction in pump efficiency because it is a highly compressible fluid.
Use of Permeability Distribution in Water Flood Calculations
Authors: Stiles Wm. E. 
Published: April 2012

Abstract
A method is presented for predicting the performance of water floodingoperations in depleted, or nearly depleted, petroleum reservoirs. The methodmakes use of permeability variations and the vertical distribution ofproductive capacity. From these two parameters can be calculated the producedwater cut versus the oil recovery. Derivations of the mathematical analogy isshown and sample calculations and curves of prediction are presented. Comparison is made of the predicted and actual performance of a typical 5-spotin an Illinois water flood.

Introduction
The use of water as a flooding medium in both depleted and "flush"oil reservoirs is gaining greater recognition and acceptance. Many of theshallower fields, depleted by primary production, have been and are beingsubjected to water injection in order to obtain some part of the large volumeof oil remaining after primary production. Some of the earlier water floodinstallation proved highly discouraging and the value of water flooding wasoften questioned. Many of these earlier floods were haphazardly selected anddeveloped as little was known of the physical characteristics and contents ofthe producing formations. The prior evaluation of the flood performance wasimpossible.
During the past decade the development of the required reservoir engineeringtools -core analysis, reservoir fluid analysis, electric logs, fluid flowformulae, etc.- has allowed the engineer to construct and apply the methodswhich are presently being used to evaluate the economic and mechanicalsusceptibility of a reservoir to flooding.
This discussion will present a method for taking into account the effectof permeability variations in predicting the performance of water floods indepleted reservoirs.

Permeability and Capacity Distribution
It is generally agreed by most investigators that in a single phase systemfluid will flow in a porous and permeable medium in proportion to thepermeability of the medium.
Producing formations are usually highly irregular in permeability, bothvertically and horizontally. However, zones of higher or lower permeability areoften found to exhibit lateral continuity. Thus, while structurally comparablestringers in adjacent wells may differ several fold in permeability values, they usually bear resemblance as being part of a general continuous higher orlower permeability section.
T.P. 2513
Effects of Transient Conditions in Gas Reservoirs
Authors: MacRoberts D.T. 
Published: April 2012

Abstract
A simple disturbance in a gas reservoir travels with a finite velocity whichis nearly independent of the amplitude of the disturbance. As a result verycomplex transients may be set up which seriously affect observation at a well.The time of transient is much longer than commonly supposed.

Introduction
A change in pressure at a gas well is not propagated through the reservoirinstantaneously but with a definite finite velocity. Knowledge of the period ofthis transient is of value because:Observations of pressure and flow-rate during the transient may affectinterpretation of back-pressure tests.Interference effects between wells may be used to determine continuity offormation.Additional information concerning the physical characteristics may possiblybe deduced from the behavior of a well during the transient.

Mathematical Development
It will be assumed that the well is initially closed in and that thepressure is constant throughout the reservoir. As the initial disturbancepasses outward from the well it is further assumed that a logarithmic pressuredistribution is established between the most distant point reached and thewell.

Conclusions
The great length of time which may be involved in transients may becalculated from the appropriate constants. Thus the Monroe gas field containsareas having transient time of the order of years. This produced the anomaly ofa field effectively depleted in one portion but with virgin pressure in anothereven though both were connected.
Some attempts have been made to establish or disprove continuity offormation by the observance of interference effects between wells. Althoughthis is theoretically possible and such interference effects have been observedthe observational difficulties are formidable and the probable existence ofcomplex transients further decreases the likelihood of an extensive applicationof this method.
The same conclusions, even more forcibly, apply to attempts to measurereservoir constants by transient observation.
T.P. 2547
Outline of Weather and Wave Forecasting Techniques
Authors: Glenn Alfred H. , Graham Joe E. 
Published: April 2012

Introduction
Oil operators engaged in drilling on the Continental Shelf of Louisiana andTexas are in agreement that adverse weather and wave action are two of thegreatest hazards to the safety and efficiency of their work. It was anticipatedwhen the offshore operations commenced that such would be the case, andexperience to date has verified this assumption. Because atmospheric conditionsand wave action involve tremendous amounts of energy it is highly unlikely thatit will be possible to control any but the most localized weather and wavephenomena within the foreseeable future. Thus, as long as the offshoreoperations involve the movement of small craft and barges over exposed waters, and the transfer of personnel and heavy equipment from these craft to eitherfixed structures or larger craft at close quarters, the weather and waveproblem will remain.
Taking into consideration the persistence of the wave and weather problemand the improbability of achieving a direct solution, the Humble Oil & Refining Company, in planning its offshore campaign investigated thepossibility of forecasting wave and weather conditions in order to providewarnings of dangerous conditions and increase efficiency in day-to-day planningof work. It was recognized that predictions of wave and weather conditionsbased on meteorology and oceanography, both geophysical sciences, are not 100per cent accurate and application of forecasts in the offshore work wasdependent on whether they provided information which was sufficiently greaterin accuracy than the layman's guess to be worth the expenditure involved.
During World War II, meteorology and oceanography were used with success inreducing danger resulting from environmental conditions and increasingefficiency of operations exposed to the elements. This success was partiallythe result of improvement in the scientific techniques involved and theprocurement and distribution of observational data, and partially due to thelarge scope of the military operations which meant that a reduction of lossesof a relatively small percentage of the total cost amounted to a large figureexpressed in terms of dollars. Since the offshore drilling involves anextremely large financial investment, it was considered that the experience ofthe Armed Services in successfully employing meteorology and oceanography mightbe duplicated in the oil industry. In addition, the oil industry's successfulexperience in utilizing seismology, geology, and terrestrial magnetism; allgeophysical sciences, indicated that meteorology and oceanography, also of thefamily of geophysical sciences and sharing their scientific assets andliabilities, might be profitably put to use.
T.P. 2546
Method of Establishing a Stabilized Back-Pressure Curve for Gas Wells Producing From Reservoirs of Extremely Low Permeability
Authors: Haymaker E.R. , Binckley C.W. , Burgess F.R. 
Published: April 2012

Abstract
A method of establishing stabilized back-pressure curves for gas wellsproducing from formations of extremely low permeability is presented. Actualwell performance under many different operating conditions is shown by thestabilized back-pressure curve. By use of the method, it is possible to conductback-pressure tests with a critical-flow prover on wells that stabilize slowly, and save approximately 88% of the gas ordinarily vented to obtain satisfactorytest data, with a great reduction in time required for testing.

Introduction
The reasons for establishing dependable back-pressure curves on gas wellshave been pointed out by previous publications. The publication most referredto, of course, is the United States Bureau of Mines Monograph 7, titled"Back-Pressure Data on Natural Gas Wells and Their Application toProduction Practices". The technique generally established therein has beenaccepted and used by many engineers; and, when proper tests are conducted, theresults can be used for the analysis and solution of several practical problemsconcerning field operation and development.
Even where formations of low specific permeability are encountered, thedetermination of a well's actual performance by the back-pressure test methodpermits the engineer to analyze many problems in individual well operation andalso to predict necessary future field development. Such problems as thedetermination of the ability of a well to produce into a pipe line at apredetermined line pressure, the design of gas gathering systems and metersettings, and the determination of the time and the number of wells required tobe drilled to meet future market obligations, can be solved, in part, by theuse of a reliable back-pressure curve. In addition, the computed well deliveryrates determined by data from backpressure tests ordered by state regulatorybodies, when compared with the true back-pressure curve, permit the operator toascertain whether such data represent unstable or relatively stabilizeddelivery rates for given pressure conditions of the well.
The technique of back-pressure testing, as described in this report, wasdeveloped by Phillips Petroleum Company engineers from data obtained during atesting program that started in 1944 and has been continued to date. Threehundred and eleven back-pressure tests were conducted on 299 wells located inthe southern part of the Hugoton Field. The gas-bearing zone is composed ofseveral dolomitic formations of the Permian Age; the important ones are theHerington, Upper Krider, Lower Krider, and Winfield. The average bottom-holetemperature is approximately 91'F., and the initial wellhead shut-in pressuresrange from 400 to 440 psig. The spacing pattern is 640 acres per well with eachwell located near the center of the section. The range of back-pressurepotentials on wells tested was from 500 to 23,000 Mcfd.
T.P. 2545
Production of Oil Under Unitization in Wertz Dome Field, Wyoming
Authors: Swedenborg E.A. 
Published: April 2012

Abstract
The unit agreement for the Wertz Dome field, Wyoming, was approved by theActing Secretary of the United States Department of the Interior on November 4,1937, effective on December 1, 1937. The stated objectives of the agreement areto conserve and put to beneficial use all oil and gas produced; to makepossible a uniform withdrawal of oil and gas in order to maintain equalizedreservoir pressures; to provide for an orderly determination of the structuralfeatures of the productive horizons; and to permit the injection of gas forpressure maintenance. The purpose of this paper is to show by a discussion ofthe problems involved and the engineering practices employed by the unitoperator, how well the objectives of the unit agreement have been accomplishedin the development and production of oil and gas from the field.

History and Development
The Wertz Dome oil and gas field is located 88 miles southwest of Casper and 38miles north and westerly from Rawlins, Wyoming. It is served by a statesecondary oiled road connecting with U. S. Highway No. 220 at Lamont, adistance of 3 miles from the field. It has been a producing field for 27 years, first as an important producer of gas and more recently of oil.
The Producers and Refiners Corp. completed Well No.1, NE?SW? sec. 7, T. 26 N., R. 89 W., the first productive well in the field, in September, 1921, in theMuddy sandstone of Upper Cretaceous age, at a depth of 3435 feet for an initialproduction of 42,000,000 cu. ft. of gas per day. In 1922 pipe lines were laidto Casper, Wyoming, for supplying fuel to the Standard of Indiana refinery, theadjoining town of Mills, and the Producers and Refiners Corp. pump station No.6in Mills; and to Parco (now Sinclair), Wyoming, for supplying that refinerywith fuel. The gasoline content of the gas was extracted in an absorption plantlocated near the town of Mills. No compressors were used as the line pressurewas sufficiently high to flow the gas through the absorbers. As high as30,000,000 cu. ft. of gas per day were treated in the plant extracting 6000gallons of gasoline. In September 1937, the pipe line was discontinued and theplant was dismantled at which time 61,000,000,000 cu. ft. of gas had beenproduced from the seven Muddy, Cloverly, and Sundance gas wells drilled in thefield. Of this volume of gas 800,000,000 cu. ft. were produced from theFrontier formation, 34,200,000,000 cu. ft. from the Muddy sandstone,24,000,000,000 cu. ft. from the Cloverly, locally called Dakota, and2,000,000,000 cu. ft. from the Sun dance formation. The pipe line wasdiscontinued because of the near depletion of the gas reserves in Wertz andnearby fields, and because of the local field requirements demanding theretention of the remaining gas reserves.
T.P. 2588
Pilot Gas Injection - Its Conduct and Criteria for Evaluation
Authors: Elkins Lincoln F. , Cooke John T. 
Published: April 2012

Introduction
Injection of gas to increase oil recovery has been considered for almost allimportant discoveries during the past ten or fifteen years. However, the numberof gas injection projects having sufficient history and data is too limited topermit valid generalities of effectiveness of gas injection. Management andengineers are faced with a difficult problem of selecting those reservoirswhich are susceptible to profitable application of gas injection.
Injection of gas to maintain high pressure favors some factors affectingreservoir performance such as viscosity, surface tension, and formation volumefactor of oil by keeping gas in solution and favors some operating featuressuch as extending flowing life of wells and storing part of the produced gasfor future use or sales. Injection of gas at low pressure involves lowercompression ratio, or at least a single gas-gathering system, largerdisplacement volume in the reservoir per unit of gas handled, and permitseffective utilization of the naturally existing energy and agent for oildisplacement that is gas dissolved in oil. Each program is thus a compromise tomeet optimum economic conditions while striving to attain maximum recovery ofthis important natural resource.
The statement has often been made that pressure maintenance would greatlyincrease oil recovery by permitting abandonment of formation oil inflated withgas in solution rather than abandonment of the same liquid volume of tank oil, if the same terminal oil saturation could be attained. Simple calculationsindicate increases in oil recovery as high as one hundred per cent on thisbasis for high formation volume factor oil encountered in current deepdrilling. Important in this statement is "if the same terminal oilsaturation could be attained."
T.P. 2646
Selective SP Logging
Authors: Doll H.G. 
Published: April 2012

Abstract
An earlier paper on the general subject of the SP log has analyzed thelimitations of that log, in particular when dealing with thin permeable bedsenclosed in thick highly resistive ones. Under such conditions, the SP log doesnot give a good definition of the permeable beds.
Selective SP logging is a new method which gives an accurate determinationof the permeable beds, even in highly resistive formations, except when thesalinity of the mud is extremely high. It also permits a close approximation ofthe static SP to be obtained.
The method consists generally in controlling the potential of auxiliaryelectrodes located in the drill holes in the vicinity of the measuringelectrode. In this manner, the flow of SP current along the drill hole ismodified to counterbalance the effect of highly resistive strata.
Several procedures and arrangements used to record selective SP curves andstatic SP curves are explained.
Field examples illustrating these methods are given and discussed.

Introduction
In an earlier paper, the shape of the SP curves and the amplitude of the SPpeaks were analyzed, considering how the circulation of the SP current isinfluenced by the subsurface media as a function of their geometricalconfiguration and their resistivities. It was shown, in particular, that thepermeable beds situated between highly resistive formations are sometimesindistinctly indicated by the deflections of the SP log.
It is the purpose of this paper to discuss a new method now being developed, namely selective SP logging, whose principal feature is to enable a moreaccurate determination of the depths of the permeable beds present in highlyresistive formations, such as occur in limestone fields.
It will be shown also how an additional curve called the static SP log can hederived from the selective SP log, or recorded directly, to facilitate theinterpretation.
T.P. 2850
Corrosion Mitigation Within Dehydrating Tanks
Authors: Kartinen Ernest O. 
Published: April 2012

This report is the accumulation of eight years of experience on only onesmall phase in the business of oil production. It is not intended as a finalreport but rather as a progress report dealing with the internal corrosion ofoil field dehydrating tanks.
The corrosion of dehydrating tanks continues to be a problem in the productionof crude oil. The deterioration by corrosion of these tanks falls into threegeneral classifications:Atmospheric corrosion of exterior areas,corrosion of the underside of deck and the rafters and top area of the upperrow of staves in that part of the tank which is known as the vapor space, andcorrosion of the bottom and shell areas, and the steam coils which arenormally immersed in water and thus exposed to the corrosive action of thewater.
Atmospheric corrosion is primarily a paint problem, and has been omitted inthis discussion.
The corrosion in the vapor space, in this company's experience, which has beenof great concern only in one area, has also been omitted in thisdiscussion.
The third, and most troublesome type of corrosion, and the one with which thisreport deals, is that which occurs in the water-exposed areas of dehydratingtanks, and, to a lesser degree, in some stock tanks.
The operating temperature of these waters varies from 80'F to 160'F and thesalt counts run from a few thousand to as high as 25,000 parts per million.Corrosion in these tanks occurs in three forms:pits,ringworm type ofattack along the vertical and horizontal bolt seams, andas a generalattack, spread over a wide area.

Steam Coils
In dehydrating tanks, our experience has been that the steam coils are thefirst to show signs of corrosion, and then the shell and bottom areas. Thisaction is not uniform throughout this company's operations. Some installationshave coil troubles with very little tank trouble, and some show just theopposite. But in the majority of cases the coils are the more seriouslycorroded areas. This may be partly due to the fact that we have tried byperiodic application to keep a protective coating on the interior areas of thetanks, and some protection has been afforded by these coatings.
T.P. 2847