bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Prospects Of Natural Gas Supplies And Markets In Europe And Their Influence On The U.S.
Authors: D&apos;Andrea Lucio 
Published: December 2007

The reason for presenting this paper to the Society of Petroleum Engineers is the realization that little coverage is given in the U.S. to natural gas developments in Europe. Perhaps this is due to the concern that both Europe and the U.S. share with regard to oil. Both depend on external sources of oil supplies significantly, even more so Europe than the U.S. It may also be due to the fact that in recent years we in the U.S. have been concerned with solving our own natural gas problems, which our European friends observed with interest, but were somewhat bewildered by our inability to arrive at a satisfactory solution.
I do not think that gas developments in Europe deserve to be ignored, if we recognize the common goal which we share with Europe of utilizing alternative energy sources in order to reduce the heavy dependency on imported oil.
Hard Decisions: A Perspective On Free World Energy Realities
Authors: Swearingen John E. 
Published: December 2007

Swearingen, John E.* Chairman of the Board, Standard Oil Company(Indiana)
Good afternoon. It is always a pleasure to visit Las Vegas, and it gives me very special pleasure to address the Society of Petroleum Engineers. Petroleum Engineers. As you know, much of the time of oil company executives these days is taken up with dealing with that huge assortment of non-oilmen in Washington who are attempting to run our industry. It is, therefore, refreshing to meet with a group of professional people who know what they are doing and how to do it I wish the people who know what they are doing and how to do it I wish the same degree of competence pertained within the federal bureaucracy.
As matters now stand, so many people and departments wield influence on energy policy that it is extremely difficult — and sometimes impossible — to develop long range plans. And without knowing the rules of the game, we cannot realistically make those hard decisions which I have been asked to discuss today.
Evaluation of CO2 Based Vapex Process for the Recovery of Bitumen from Tar Sand Reservoirs
Authors: Khelifa Talbi , Maini Brij B. 
Published: December 2007

Abstract
The vapour extraction (Vapex) process has recently gained considerable attention for its promising application for the recovery of heavy oil and bitumen reservoirs that are deemed unsuitable for thermal methods. In conventional Vapex process, a mixture of vaporized solvent (propane and/or butane) and a commercially available non-condensable gas (methane, natural gas) is injected into the reservoir to reduce the oil viscosity. Therefore, the cost of these injected gases per barrel of produced oil is critical for the economic viability of the process. With predicted increase in the gas prices, the process has lost some of its initial attraction.
For reducing the solvent cost, the injection of CO2 as a non-condensable gas appears to be an attractive alternative. The advantage of this low cost alternative is that the solubility of CO2 in heavy oils is significantly higher than that of methane. Consequently, the mixture of propane and CO2 can provide greater reduction in oil viscosity compared to the equivalent mixture of propane and methane. In addition, this CO2 injection can play a significant role in sequestering CO2 emissions. However, the CO2-propane-heavy oil system shows complex phase behaviour, forming multiple liquid phases. Such multiple liquid phases can reduce the effectiveness of gravity drainage process by introducing complex relative permeability effects.
This paper presents an experimental study aimed at developing a new CO2 based Vapex process for in situ recovery of bitumen from tar sand reservoirs. The experiments have been performed in a partially scaled physical model at different operating conditions. The main conclusion from this study is that the CO2 based Vapex process is more cost effective and environmentally friendly than the conventional Vapex process.
Extended Brigham Model for Residual oil Saturation Measurement by Partitioning Tracer Tests
Authors: Tang Joseph S. 
Published: December 2007

Abstract
Brigham’s model has been used extensively in the petroleum industry for the design and interpretation of interwell tracer tests. The model is based on correlation and has included physical dispersion as an input parameter. In spite of its limitations, the model is useful in estimating layer heterogeneity, layer distribution, permeability contrast and dispersion in the reservoir. However, the model can only handle non-partitioning tracers that have no solubility in oil. With the advancement in partitioning tracer technology and interpretation technique, interwell partitioning tracer test has gained its popularity, especially in China, for determining residual oil saturation Sorw between wells. Partitioning tracer test also finds its application in environmental protection, where the test is routinely run to determine the amount of non-aqueous liquid phase NAPL trapped underground due to spill or seepage. While sophisticated streamline or finite difference simulators have been increasingly used to determine Sorw distribution from the tracer production data, simple semi-quantitative model still has its merits in providing a direct, unambiguous estimate of average Sorw along the tracer flow path. This paper broadens the scope of the original Brigham’s model by incorporating partitioning tracers into the model using a chromatographic transformation technique. By matching the partitioning and non-partitioning tracer curves, Sorw can be determined by layers. The extended Brigham model was applied to the Ranger oil field multiple tracer test and the residual oil saturation determined compared favorably with those obtained by chromatographic transformation method and numerical simulation.
The Effect of Treating Agents on the Electro-Chemical Activities of Drilling Mud Filtrates
Authors: Lipson Leonard B. , Overton Harold L. 
Published: December 2007

Abstract
The formation water resistivity is presently calculated from electric log data with the assumption that both the waters in the drilling mud and the formation are essentially sodium chloride solutions. This is found to be in error with most of the drilling muds in use today. This paper treats the effect of mud chemicals on formation water resistivity when SP data is used for the water resistivity calculation.
The Nernst equation for activities of ionic solutions, that are essentially univalent, is used to evaluate the spontaneous potential. This equation is:
(Equation)
Eq. 1 has both a shale membrane and a liquid junction component. Only the shale membrane component was investigated in this study, since it is usually the most significant parameter. It may be expressed as:
(Equation)
Since the activity of the mud filtrates must be known for given resistivities, both of these parameters were measured in this investigation. The results showed that several properties which are being measured at the well head can be used to find the activity of a mud filtrate if the resistivity is known. The activity of mud filtrates rarely varies with the sodium chloride in solution alone. Important properties causing activity changes are filtrate alkalinity and calcium content. Graphical representations are prepared showing the correlation with each of these parameters.

Introduction
C. and M. Schlumberger and E. G. Leonardon in 1934 considered the self potential curve of electrical logging to be composed of the combination of a streaming potential and a boundary potential. They believed that the boundary potential was set up at the face of impermeable material, such as clay or shale, due to the interaction of fluids containing different salt concentrations. The electro-chemical component of the self potential curve was given as
(Equation)
where K is an unknown constant, Rm is the mud resistivity, and Rw is the connate water resistivity.
Exceeding Drilling Performance and Environmental Requirements with Potassium Silicate Based Drilling Fluid
Authors: Duncan Jayne , McDonald Michael 
Published: December 2007

Abstract
Since the re-introduction of silicate based drilling fluids, the vast majority of wells have been formulated around sodium silicate. Somewhat surprising, it is only recently that potassium silicate has become the alkali silicate of choice for use on-land. Described are the chemistry, drilling and environmental performance of potassium silicate. Field results are presented for a series of wells drilled in British Columbia, Canada using a potassium silicate based drilling fluid. These results show that drilling objectives were exceeded and further demonstrated ease of disposal with minimum impact on the environment.
Methods for Calculating Profitabilities
Authors: Brons F. , McGarry M.W. 
Published: December 2007

Abstract
To rank a variety of ventures in the order of their profitability, a yardstick is needed in which both the profit and the time at which this profit is realized are included. This paper describes methods for evaluating two of the more common yardsticks, i.e., the present day value or the total profit for a fixed interest rate and the internal rate of return. No attempt is made to present arguments in favor of either of these criteria. Based on a number of simplifying assumption, tables and graphs have been prepared with the aid of which the profitability of single incomes, constant incomes, and three types of declining incomes can be calculated for a wide range or interest rates. Two examples are given to explain the use of the graphs and tables.

Introduction
The total profit of a venture is by definition the difference between the total net income and the capital investment. Where, as is usually the case, the investor has a choice of ventures in which he can invest his money, he will need a single yardstick to rank these ventures according to their profitability. It is at once obvious that the total profit cannot always be a sufficient criterion: a smaller profit returned to its investor after a short time may be more desirable than a larger one, for which the investor has to wait a long time. A yardstick by which ventures can be ranked uniquely according to their degree or profitability must therefore incorporate the monetary value of the profits and the time at which they are returned to the investor.
Several yardsticks are being used in the oil industry which more or less approach this criterion. In the present paper only two will be considered:
the present day value (or deferred value) or the total profit, and
the internal rate of return ["yield", "earning power", "rate of return," etc.]
Optimization of a 3D Seismic Survey Onshore Abu Dhabi – From Field Tests to Final Design
Authors: Al Jeelani Abu Baker , Marmash Samer , Bin Ishaq Abdul Salam , Al-Shaikh Ahmed , Kleiss Erik , Al Shamsi Ali , Haggag Ismail , Marsden Paul 
Published: December 2007

Abstract
Reservoir heterogeneties play important roles in reservoir description processes. It is therefore imperative to understand the source of uncertainties influencing structural and stratigraphic interpretations of reservoirs.
An integrated reservoir, and seismic modeling study over an onshore giant field in Abu Dhabi came to the conclusion that 3D seismic is the most efficient approach to detect the reservoir heterogeneiy and structural uncertainties that are thought to be responsible for the irregular fluid flood front advance and consequently for the reservoir management problems.
In preparation for a large vibroseis 3D seismic survey over the subject field, 2D and 3D field tests were carried out to determine optimum source energy distribution. Several versions of the 2D and 3D data were acquired with different source geometries and processed up to stack, migration and inversion (for 3D). The 2D test showed that in this area final data quality does not depend on vibroseis sweep length (i.e. source energy). A subsequent 3D test showed that final data quality is marginally dependent on dense source arrays, but is enhanced considerably using a finer areal distribution of source points. This could be used to improve the data quality and at the same time to reduce the cost of the subsequent production 3D survey.
Completion Practices for Prudhoe Bay Wells
Authors: Knepler J. R. 
Published: December 2007

Abstract
The purpose of this paper is to present an overview of the current completion practices for wells in the Eastern Operating Area of the Prudhoe Bay Field. ARCO Oil and Gas Company is the operator of the Eastern half of the Prudhoe Bay Field and SOHIO Petroleum Company operates the Western half. Completion practices in general are similar in both operating aroas; however, there are a few significant differences. This paper refers to practices in the ARCO Oil and Gas Company operating area only.
With only two and one-half years of production behind us, there is relatively little history on Prudhoe Bay wells, but we have produced a billion barrels of oil in that short time. The operators have drawn on what is believed to be the best available practices in the industry in developing their operating plans for Prudhoe. There is no universally right way to complete all wells, and we believe we are doing what is best for our situation. In this paper we hope to present the perspective of how and why wells are completed the way they are at Prudhoe Bay.
The primary consideration in every completion design is the prudent maintenance of the safety and integrity of the well throughout its life. In addition, all completions are designed to accomplish two basic things: 1. To minimize formation damage or maximize well productivity; 2. To provide maximum flexibility over the life of the well. It is through diligent adherence to these goals that the optimum economic benefit is realized from each completed well. This paper describes the basic completion practices utilized at Prudhoe Bay to achieve these goals.
Reservoir Stimulation of Dirty Sandstones
Authors: Davies David K. 
Published: December 2007

Abstract
Approximately 80 percent of the world's sandstones can be classified as "dirty".1 However, dirty sandstones contain only 15 percent of the world's oilfields.2 Most oilfields have been discovered in clean sandstones. Differences in success ratios between clean and dirty sandstones suggest either that: 1. dirty sandstones do not contain recoverable hydrocarbons (particularly oil), or 2. hydrocarbons are more difficult to extract from dirty sandstones than clean sandstones. Commercial quantities of hydrocarbons have been discovered in dirty sandstones.3 This strongly suggests that their hydrocarbon potential is good. However, detailed studies of the composition of dirty sandstones indicate that they are highly susceptible to formation damage during both drilling and stimulation. Care and attention to rock mineralogy and fluid composition can minimize or prevent formation damage in dirty sandstone reservoirs. With properly designed stimulation procedures, 80 percent of the world's sandstones (the dirty sandstones) become highly prospective and good exploration targets.
The terms "clean" and "dirty" sandstones are used (and often misused) widely in the petroleum industry. Clean sandstones are comprised dominantly of sand grains which are chemically stable and physically durable. On the other hand, dirty sandstones are comprised dominantly of sand grains which are chemically unstable and physically non-durable (Figs. 1 and 2). Note that the terms clean and dirty do not involve the amount of clay or shale in the sands. Both clean and dirty sands can be clay-rich or shaly. Distinction between clean and dirty sands is thus based on the composition of the sand sized particles, not the relative abundance of clay or shale.
Reservoir stimulation in dirty sandstones has, as its principal aim, the enhancement of rock permeability. In order to predict the effects of specific stimulation efforts, it is necessary to first understand the reasons for low permeabilities and porosities in many dirty sandstones. Specific stimulation efforts should be designed to attack either the principal cause of porosity-permeability reduction, or those causes which can be treated with the present state of the art.
The Use of Floating Production Systems To Evaluate Marginal Reservoirs
Authors: Caycedo Luis , Seay F. T. 
Published: December 2007

Abstract
There are marginal oilfield discoveries in Indonesia which cannot justify installation of fixed production platforms but can still be economically developed. The solution to these marginal oilfields is the utilization of unique Floating Production Systems (FPS). The FPS is becoming more accepted as off-shore construction costs continue to increase and these relatively low-cost production facilities are proving to the most economical method of production in marginal fields such as encountered off the coast of Indonesia. These FPS's are self-contained, complete with modern accomodation for production personnel and are equipped with the latest in production systems.
Such floating production systems are currently operational in the Aijuna "MM", "FF" and "F" fields, Java Sea, for Atlantic Richfield Indonesia and they are proving to be attractive in determining reservoir behaviour, probable reserves and are proving to be ideal in minimizing initial capital expenditures required for permanent production platforms.
This paper is intended to describe the economics of the unique Floating Production Systems and to also discuss the selection of equipment and operational experience.
Udang Field: A New Indonesian Development
Authors: Mattes Earl M. 
Published: December 2007

Abstract
The Udang Field is located in the Natuna Sea, approximately 1,000 kilometers North of Jakarta. The discovery well was drilled in 1974. Field commenced production 18 January 1979. It now has 10 wells producing about 25,000 BOPD. A total of thirteen wells have been drilled.
Facilities installed consist of a 4,500-ton drilling and production platform supported on eight piles driven 320 feet into the ocean floor. The platform, the biggest in Indonesia, is connected by a 400-foot bridge to a flare tripod. Production facilities capable of processing 40,000 barrels per day of high pourpoint crude are installed on the platform. Processed crude is pumped through dual insulated pipelines to the Udang Natuna, a 93,000 deadweight-ton tanker which is permanently moored 6,100 feet from the platform by a single point mooring system. Export tankers breast moor alongside the Udang Natuna to receive finished crude.
A total of 24 months elapsed between commitment to the project and completed development.
Efficiency Of Offshore Production Via An SPM System
Authors: Warren J. 
Published: December 2007

Abstract
In recent years, offshore exploration efforts were extended into deeper and deeper water located further and further from shore in less and less hospitable enviomments. Consequently, not all of the fields discovered were feasible – economically and/or technologically – to develop and to produce using established methods. To improve this situation, a transportation system was developed which allowed crude-oil tankers to be loaded via a single-point mooring buoy, SPM, located near a producing platform – thus, the need for expensive, deep-water pipelines was reduced.
Despite this innovation plus additional improvements, many discovered fields still remain in the marginal category for conventional evaluation. Therefore, it is necessary to optimize the total production/storage/transport system before consistently rational decisions can be made regarding field development.
This paper presents a method for predicting the behavior of an SPM system – considering the effects of tanker size, number of tankers, deviations from schedule, weather, loading rate, storage capacity and production rate( The primary descriptive factor determined by this approach is the operating efficiency of the storage/transport system which constitutes a constraint on the production system. Since the production system can be optimized on an economic basis while recognizing well productivity and reservoir performance, it is possible to specify the optimal configuration for the entire system – and to assure the compatibility of the upstream and downstream elements.
The analysis of the SPM system, a procedure for optimizing the production system and a discussion of the upstream-downstream coupling – and its effect on the optimization of the entire system – are presented in this paper. A simple, but complete, example is also included.
Diagnosis of Bacterial Sulfide Problems in Secondary Recovery and Salt Water Disposal Water Injection Systems
Authors: Moore Burton H. 
Published: December 2007

Abstract
Expense of bactericide treatment in injection water can be a major item in the operation of a waterflood or disposal system. Each operator of such a system desires to know whether such expense is necessary and which bactericidal chemical is most economical for his system. The diagnosis to be described makes use of modifications in recognized analytical methods for on-the-spot determinations of total sulfide and of populations of "sulfate-reducing bacteria". Activity of the bacteria is judged on the basis of increases in sulfide concentrations and/or in increases in bacterial populations as the water progresses through the system under study.
The methods used in this diagnosis are of sufficient sensitivity that indications of bacterial activity should be apparent if down-hold bacterial sulfide formation is a significant factor in any water injection system. If the diagnosis fails to show a definite bacterial problem, more careful study of other factors is indicated.
Descriptions will be made to cover typical evidence for:Uncomplicated appearance of bacterial sulfide in injection water accompanied by increasing numbers of sulfate-reducing bacteria or accompanied by high bacterial populations.Localized pockets of bacterial sulfide formation. Water passing such pockets would pick up sulfide and bacteria either continuously or in "slugs".Cases where one or more supply waters contain dissolved sulfide with or without significant numbers of sulfate-reducing bacteria. Little or no additional sulfide is formed by the bacteria but the soluble sulfide reacts with iron salts, metallic iron etc., to produce "black water". Treatment with chemicals having properties other than or in addition to bactericidal activity is required.Complications associated with imperfect mixing of widely differing supply waters.
Concentrations of sulfide and bacteria passing sample points fluctuate, hence diagnosis is possible only by alterations in the operation of the system.
A Comparison of Caustic Soda and Soda Ash as Chemical Media for SO2 Recovery in Oilfield Steam Generators
Authors: Siemak John B. , Reyes Ricardo B. 
Published: December 2007

ABSTRACT
Caustic soda and soda ash were used as an alkalinity source in the liquid scrubbing of SO2 in flue gases produced from crude oil-fired steam generators used in thermally-enhanced oil recovery. It was found that caustic was utilized more efficiently, thereby allowing the SO2 scrubber to run at a lower pH with a higher SO2 removal capacity. Also, overall economics favored the use of caustic over soda ash in this scrubbing application.