bluuebunny/crossref_metadata_2025_split huggingface dataset:
Correlation of Activity Coefficients for the System Methane-Ethane-Propane At Low Temperature
Authors: Bukacek Richard , Leipziger Stuart 
Published: December 2007

This paper was prepared for the 48th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Las Vegas, Nev., Sept. 30-Oct. 3, 1973. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
The method of stepwise regression has been used to evaluate the parameters in the fourth-order Margules representation of activity coefficients for the system methane-ethane-propane. Binary and ternary data in the temperature range from 50 to 225 degrees F and pressure range to 800 psia have been correlated. Activity coefficients psia have been correlated. Activity coefficients are found represented with a standard deviation of about 5 percent. The value of the stepwise regression procedure is illustrated.

Introduction
In prediction of vapor-liquid equilibria, activity coefficients play a key role in defining departure from ideal behavior in the liquid phase. Since activity coefficients are best estimated on the basis of experimental measurements, and since highly accurate vapor-liquid equilibria data are difficult to obtain, development of methods for treating these data are of considerable interest. It is usual to evaluate the binary interaction terms by use of binary data and a correlation device such as the Margules equation. In such a procedure, the ternary data available are used only for testing the resulting correlation, and perhaps to determine values for higher-order perhaps to determine values for higher-order interaction terms. The purpose of this paper is to illustrate the use of stepwise regression in correlating data on multicomponent mixtures and determining which correlation parameters are relevant. By this technique all of the pertinent data contribute to determination of the pertinent data contribute to determination of the useful parameters.

EVALUATION OF ACTIVITY COEFFICIENTS
In this work we have followed the convention of Prausnitz and his coworkers, as summarized by Zellner et al. Thus, activity coefficients may be defined from experimental measurements as follows.
Use Of The Temperature Log For Determining Flow Rates In Producing Wells
Authors: Curtis M.R. , Witterholt E.J. 
Published: December 2007

This paper was prepared for the 48th Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Las Vegas, Nev., Sept. 30-Oct. 3, 1973. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
In the literature on Temperature logging, relationships exist which may be used to predict the temperature responses in producing wells as a function of volumetric flow rate, time of production, fluid gravity, geothermal gradient, and various thermal coefficients. These relationships indicate that under "ideal conditions" the temperature curve recorded above a producing zone as a function of depth exponentially approaches an asymptote parallel to the natural geothermal profile. This asymptote is displaced from the geothermal profile by an amount depending on the mass flow rate and the time the well has been produced. Theoretical examples will illustrate the use of these relationships to predict the temperature responses in producing wells for cases of flow rates up to 1,000 B/D producing wells for cases of flow rates up to 1,000 B/D and for production times up to 1,000 days. With the knowledge of the predictive equations, the reverse problem is considered. Temperature logs are examined to locate intervals exhibiting this exponential behavior. A coefficient in the basic relation is adjusted to make the relation fit a given exponential segment. Then, knowing the time the well has been produced, the mass flow rate is computed. If fluid-density information is available, the volumetric flow rate is computed. This method has its greatest applicability when used in conjunction with spinner-type flowmeters to detect fluid flow in the casing annulus. For use of the method, production times should be greater than 10 days, and producing zones should be separated by at least 100 feet.
How Amoco Approached Automation in West Texas
Authors: Wadlington W.H. 
Published: December 2007

Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Amoco's position in West Texas is rather unique in that we have a high concentration of wells in a relatively small geographical area. This situation caused us to take a different approach to automation from any other in the producing industry that we know of today. Amoco's operations in West Texas include four Area offices and about 5,000 producing and water injection wells which are prime producing and water injection wells which are prime candidates for computerized automation.
The basis for our approach to automation in West Texas was developed from information learned from a pilot project in the Smyer Field in Hockley County, Texas. This pilot project was designed to test all applications which reasonably offered an opportunity to reduce labor or accelerate production. As a result of this pilot, we decided that future Amoco operated automation projects in West Texas would be based around the following concepts:Pumpoff Control of Beam Pumped WellsAutomatic Well TestingData GatheringAlarm Monitoring
These basic concepts permitted developing modular standard software applicable to all West Texas projects. projects. Once the basic concept for automation in West Texas was established, it was then necessary to develop an optimum computer system for this large number of wells. Economics and other advantages dictated that a Master-Mini, two level, hierarchical computer system would be best.
The plan established for automation in West Texas included running multi-conductor cable to each producing well for pumpoff control and monitoring various statuses. It soon became evident that with conventional telemetry equipment available at that time, cabling costs would approach $1,100 to $1,200 per well and would be prohibitive. The obvious way to reduce cabling costs was to increase the number of RTU's which would in turn reduce cabling costs. We finally interested one telemetry vendor in designing and developing a small RTU referred to as a Mini RTU. We believe this was the first telemetry gear actually designed primarily to meet the requirements of oilfield automation.
The Poromechanical Behaviour of Felser Sandstone: Stress- and Temperature-Dependent
Authors: Hettema M.H.H. , de Pater C.J. 
Published: December 2007

Abstract
We report an experimental study on the poromechanical behaviour of a sandstone rich in clay minerals. With the use of Biot's theory of poro-elasticity, results obtained from mechanical experiments performed in a triaxial cell at temperatures up to 200 C are compared with results of acoustic experiments performed under atmospheric pressure at room temperature. The sandstone exhibits non-linear stress- strain behaviour depending on pore water saturation and temperature. The poro-elastic parameters were also found to be stress and temperature dependent. Inconsistencies found between the parameters determined by various independent experimental techniques show, that the theory of poroelasticity does not describe the pore volume changes of this clay-rich sandstone well.
P. 347
The Assay of Chemicals for Oilwell Stimulation
Authors: Mancillas Gene , Burroughs James E. 
Published: December 2007

This paper was prepared for the Society of Petroleum Engineers of AIME Symposium on Formation Damage Control, to be held in New Orleans, La., Feb. 7–8, 1974. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon requested to the Editor of the appropriate journal, provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Mixtures of hydrochloric and hydrofluoric acids have been successfully used in the stimulation of sandstone reservoirs. Occasionally, however, an inadequate response to these acids results and in some cases additional well damage has occurred. This poor response may be partly due to the improper concentration partly due to the improper concentration of HC1-HF acid used in the treatment. Laboratory data show that the concentration of an acid formulation can have a significant influence on the results of a treatment. This makes the rapid and accurate assay of the acid solution to be used, an important factor in a successful treatment design.
This paper will describe an analytical procedure that employs a mixed titrant in procedure that employs a mixed titrant in conjunction with ion selective electrodes and Gran's Plots to determine the amounts of hydrochloric and hydrofluoric acids in mixtures. The proposed procedure will be compared to other analytical methods and the effect of (other experimental parameters and contaminants will be discussed. It will be shown that the method can be routinely performed by semi-skilled technicians under performed by semi-skilled technicians under field conditions. The procedure was tested for precision and accuracy on laboratory and field prepared acid mixtures. Analysis of field mixtures using this procedure reveal that conventional field mixing methods do not always produce uniform solutions.

Introduction
The use of hydrochloric-hydrofluoric acid mixtures in matrix treatments of sandstone formations can be effective in stimulating production and injection wells. Occasionally however, an inadequate response to these acids results and in some cases additional formation damage occurs. This poor response may be partly due to the poor response may be partly due to the improper concentration of acid used in the treatment.
Sand Detection In Production Lines
Authors: Vriezen P.B. , Wunnink G.J. 
Published: December 2007

Abstract
Two systems have been developed for the detection of sand in surface gas lines. One systemis based on the detection of sand grain impacts on a piezoelectric crystal and the other uses anerodable resistor placed in a gas stream. Laboratory experiments and tests on the well site have proved the suitability of both techniques. Quantitative calibration of the two systems under operational conditions is in progress.

Introduction
In areas where Band production of oil or gas wells forms a potential problem, it is advisable to install sand detection devices. Early remedial action on a sand producing well will increase the chance of success of the treatment. To ascertain the need for such action, the sand detectors should preferably provide quantitative information on a continuous basis.
Apart from conventional wellhead sampling, only one system of sand detection is known to be in use. With this method a preselected level of erosion is detected by the sudden pressure change in a thin-walled metal capsule when it is finally penetrated by the sand. At least two continuously monitoring sand detection systems have been proposed. One system uses an erodable radioactive disc; metal losses due to erosion are determined by measuring the resulting decline in the level of radioactivity of the disc. The other method has been proposed by Stein et al. for downhole detection of sand influx in a well. He states that the additional noise generated by sand impingement ontubing is proportional to the total kinetic energy per unit time of the impinging particles. The mass flow of the sand produced is derived from the actual acoustic noise level minus the level that is expected at given flow conditions.
As no suitable continuously monitoring sand detection system was known to be commercially available, scouring experiments were initiated, which resulted in the development of two prototype detection systems. In the first system apiezo-electric crystal is used to produce sand impact signals. Only those impacts can be detected whose peak amplitude can be discriminated from the background noise caused by the turbulent gas stream. The amount of sand produced can be derived from the number of impacts counted, the amplitudes of their signals and the velocity of gas flow. The system has to be calibrated under actual field conditions. The second system involves direct measurement of the erosive effect of sand in a gas stream. It is based on measurement of the increase in resistance of an erodable resistor which is placed in a sand-laden gas stream. Adequate sensitivity can be achieved by selection of suitable erodable elements. Here again calibration under field conditions is necessary.
Operations Carried Out on a Subsea Wellhead in a Water Depth of Approximately 210 Feet
Authors: Houot Georges , Issarte Jean-Pierre 
Published: December 2007

This paper was prepared for the SPE-European Spring Meeting 1974 of the Society of Petroleum Engineers of AIME, held in Amsterdam, the Netherlands, May 29–30, 1974. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Netherland Section of the Society of Petroleum Engineers, P. O. Box 228, The Hague, the Netherlands. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
A subsea completed oil well lying offshore Congo was brought into production with the aid of a 48 m × 16 m barge carrying production, stimulation and wire line production, stimulation and wire line equipment.
The success of the operation was mainly due to the use of a subsea lubricator and associated barge-mounted swell compensating device.
The feasibility of bringing subsea completed wells into production working from a floating support was amply demonstrated by this successful operation.

Introduction
The great majority of wellheads in offshore fields either producing or under development are installed above the surface of the sea on fixed platforms. In water depths of 70/100 m (230/330 ft) and over, the installation of such platforms is difficult and very costly. For this reason, when possible, deviated wells are drilled so as to group together a large number of wells, up to 25 or 30, on one platform. This solution cannot always be adopted, however, as for example in the case of shallow pay zones, where deviated wells would not drain a sufficiently large area.
It was obvious that alternative methods of developing such offshore fields would have to be sought using wellheads installed on the sea bed. In fact in very deep water this would appear to be the only practicable method of producing.
Such subsea completions could use "wet" type wellheads either with or without temporary capsule or "dry" wellheads with permanent capsule. The system we present is for use on the "wet" type of wellhead.
Mud Displacement In Primary Cementation
Authors: Zuiderwijk J.J.M. 
Published: December 2007

Abstract
Displacement experiments were carried out in a pilot-plant model, to arrive at means of improving zonal isolation. Scaled and full-sized annuli, with and without hole enlargements, were simulated. Various displacement fluids were investigated. The amount of mud left behind was derived indirectly by measuring the remnant radio-activity caused by the mud, containing a radio active tracer. Special attention was given to the influence of hole enlargements, fluid velocity, density and rheological properties of mud and displacing fluids on the mud displacement. The most significant parameters were found to be the displacement velocity and the flow properties of the fluids. The study showed that depending on the conditions and the properties of mud and displacing fluids, a good displacement efficiency can be achieved both for low and high displacement rates.

Introduction
Lack of zonal isolation believed to be caused mainly by inadequate mud removal, the presence of an excessive mud filter cake and contamination of mud and cement.
A considerable amount of work has been carried out and is published, in this field. However, opinions on how to solve the various problems encountered are still divided and there is no clear insight into the importance of parameters such as fluid velocity, density and rheological properties of mud or cement and the use of preflushes. In addition many studies on this subject were based upon small test series with scaled models.
In experimental studies carried out at the Koninklijke/Shell Exploratie en Produktie Laboratorium, Rijswijk (The Netherlands), a different set-up was used which permitted large series of experiments to be carried out in which one parameter could be varied at a time.
Based on the results of some 270 tests, conclusions could be drawn on the relative importance of the various parameters that influence mud/cement displacement and parameters that influence mud/cement displacement and thus zonal isolation.

THE MUD/CEMENT DISPLACEMENT PROCESS
After drilling the borehole and running the casing the following situation will prevail in the borehole;
-the space between casing and borehole is filled with mud,
-a mud cake is present on the borehole wall; its thickness varies from significant in places opposite permeable zones to virtually nil at locations opposite impermeable zones, e.g. shale layers,
-a gauge hole with washed-out sections.
Ideally, the mud cake and all the mud should be fully displaced by the cement slurry to obtain a good solution between different zones.
The Merits of Some Alternative Development Plans For Offshore Oilfield Development
Authors: Cline W.B. , Heather D.I. 
Published: December 2007

This paper was prepared for the SPE-European Spring Meeting 1974 of the Society of Petroleum Engineers of AIME, held in Amsterdam, the Netherlands, May 29–30, 1974. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Netherland Section of the Society of Petroleum Engineers, P. O. Box 228, The Hague, the Netherlands. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
The paper relates the financial performance requirements of offshore oil and gas performance requirements of offshore oil and gas development projects to the technical risks associated with such programs and the financial circumstances of the participating group. The minimum negative cash participating group. The minimum negative cash flow approach, with higher levels of operating costs, is compared to the high capital investment exposure approach, with corresponding lower operating costs, in terms of an example situation.
The writers then go on to broadly review the more recent development proposals for North Sea applications and proposals for North Sea applications and outline where the degree of flexibility for each plan generally places it in the context of risk capital exposure.

Introduction
Not too many years ago it would have been almost unthinkable for an operator to take the decision to initiate a full scale major oilfield development scheme on as little evidence as may be available from the discovery well; as few as two confirming appraisal wells plus the detailed seismic survey results. Yet due to the substantial emergence of offshore oil and gas development projects in increasingly arduous circumstances, the trend toward the necessity for far more expensive decisions based on less and less confirming technical data, is fast becoming an accepted fact of life.