bluuebunny/crossref_metadata_2025_split huggingface dataset:
Practical Application of a Multiple-Survey Magnetic Correction Algorithm
Authors: Brooks A.G. , Gurden P.A. , Noy K.A. 
Published: December 2007

Abstract
Conventional methods for drillstring magnetization compensation of magnetic surveys process each survey independently. Limitations of these methods include the need for an accurate estimate of the local magnetic field, while they often result in excessive scatter in corrected azimuth values and poor accuracy in attitudes near horizontal east-west.
Recent developments in survey processing include corrections which operate on several surveys simultaneously. The additional information thus obtained can be used to determine biases and other parameters affecting three axes, without the need for precise estimates of the local magnetic field strength and dip angle. Surveys processed in this way show more stable azimuth values and retain greater accuracy in the critical attitudes near horizontal east-west. The use of a multiple-survey correction technique together with in-field referencing to monitor changes in the local field addresses two major shortcomings in magnetic surveying.
Multiple-survey analysis can be used to monitor performance of accelerometers as well as magnetometers. Accelerometer variance is measured but not routinely used to make corrections when there is no significant improvement. The better practice is to use calibration values obtained in the workshop, rather than replacing them with measurements taken in the down hole environment.
The benefit of the technique is in closely monitoring sensor performance and identifying suspect surveys. Real-time verification that the tool is operating within a modeled error budget improves the value of positional uncertainty calculations. The improvement in quality control can obviate the need to run additional surveys for verification purposes.
P. 379
Retrievable Fluid Control Valve Provides Economical Placement Of Chemicals
Authors: Knox John , Hyde Walter , Scott T.A. 
Published: December 2007

This paper was prepared for the Rocky Mountain Regional Meeting of the Society of Petroleum Engineers of AIME, to be held in Billings, Montana, May 15–17, 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 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
Low fluid level wells constitute a large percentage of all the wells in the world. Stripper wells are more important today because of the higher price for their production. price for their production. Many types of production problems plague these wells. Because they take plague these wells. Because they take treating fluid on a vacuum resulting in short contact time or take excessive fluid, it is difficult to maintain production or to stimulate them. production or to stimulate them. A large number of chemicals have been developed to solve downhole problems but because of inadequate problems but because of inadequate placement techniques, have either been placement techniques, have either been relegated to failure or to a lesser degree of effectiveness than is expected.
Placement problems have now been solved by a new retrievable fluid control valve which is more versatile than prior tools.
This retrievable fluid control valve can permit the placement of chemicals down hole without pulling the tubing. the valve can be run and retrieved through the tubing on a wire line or dropped until it lands in the pump seat or a seating nipple placed in pump seat or a seating nipple placed in the tubing for that purpose.
This tool can also be used with packers for multiple treatments, packers for multiple treatments, allowing the packers to be moved while the tubing is full of chemical. Accurate placement of a small volume of expensive placement of a small volume of expensive chemicals is possible because the unique design permits the valve to be wide open while pumping through it, however, the column of fluid will be supported when injection stops.
A large number of field jobs with many different types of chemicals have proven its efficacy. proven its efficacy.
MER: Ultimate Recovery and Production Rate
Authors: Savage W.K. , Thachuk A.R. , Beykpour Hassan , Lohrenz J.H. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the Rocky Mountain Regional Meeting of the Society of Petroleum Engineers of AIME, to be held in Billings, Mont., May 15–16, 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 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.

Summary
Reservoir simulation studies were conducted on selected reservoirs to establish the relationship between ultimate recovery and reservoir withdrawal rate. The rates ranged from far above to far below normal production practice.
The simulation results indicate that for each reservoir and each development plan an MER curve, a curve of ultimate recovery versus reservoir withdrawal rate, can be determined given the necessary data. These curves show varying, but often pronounced, increases in ultimate recovery as withdrawal rate decreases.
The sensitivity of ultimate recovery to production rate may be affected to varying degrees by well spacing, well completion practices, fluid properties, reservoir heterogeneities, reservoir type and exploitation scheme. Results of studies on some of the parameters are presented.

Introduction
Conservation in the oil and gas industry dates back to the late eighteen hundreds and historically has dealt with the prevention of "reasonably avoidable waste of oil and gas". Legislators and conservation officials have conceived numerous means of regulating this concept. In a comprehensive review and discussion of conservation efforts by members of the Interstate Oil Compact Commission (IOCC) in 1965, it was found that the concept of MER (Maximum Efficient Rate) was a predominant method of preventing avoidable waste of oil and gas. In 1971 the federal government announced its intention to adopt MER as a means of regulating production on the outer continental shelf and in 1974 format production on the outer continental shelf and in 1974 format regulation by MER will be initiated in the form of OCS Order Number 11 which adopts the following definition of MER: "the maximum sustainable daily oil and gas withdrawal rate from a reservoir which will permit economic development of that reservoir without detriment to ultimate recovery".
It is to this definition of MER that this paper addresses itself.
Remarks by Philip L. Essley, Jr. Deputy Assistant Administrator for Policy Analysis and Evaluation Federal Energy Office Before The Society of Petroleum Engineers Symposium on Improved Oil Recovery
Authors: Essley Philip L. 
Published: December 2007

Tulsa, Oklahoma
Monday, April 22, 1974
Members of SPE, Guests:
It is an honor to speak to a group of my fellow society members. Particularly at a meeting where the theme involves a subject so vital to the welfare of this country.
My purpose today is to give you some impressions of what may be ahead, and some action required, as seen from the viewpoint of a long-time petroleum engineer recently turned Washington bureaucrat.
I am sure that every member of this audience is aware that we have crossed a divide in history and are now facing a new energy watershed - that will involve new problems and require new solutions. Instead of abundant cheap energy which contributed both to the wealth of this country and our extravagant use of such energy, we now face an era of scarce, high cost energy that will require major changes in our life styles. How we handle energy will represent some key policy decisions of this decade, affecting our foreign policy, monetary policy, foreign trade, inflation, growth and employment.
A Semi-Implicit Method for Simulating Reservoir Behavior
Authors: Seth Mohan S. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
A method to simulate multiphase flow behavior in reservoirs is presented that employes spatially varying degree of implicitness with respect to fluid saturations. By suitably defining the implicit region, the technique preserves the stability associated with simultaneous solution and computationally superior to it. Furthermore, the time truncation error is lower than a fully implicit formulation. Comparisons are presented for water-oil and 3-phase (with dissolved gas) coning systems and a gas percolation problem.

INTRODUCTION:
Multiphase flow behavior in reservoirs is described by a set of non-linear differential equations that are obtained by combining the continuity equations with the Darcy's law. These equations are generally solved numerically by variants of one of the following formulations:

1. Implicit Pressure Explicit-Saturation Method (IMPES)
In this approach the governing differential equations are reduced to a set of finite-difference equations with single dependent variable as the oil-phase pressure. Such a reduction to a pressure equation is carried out by combining the flow equation of each phase in a manner that eliminates the time derivatives or differences of saturations. The procedure treats the saturation dependent terms explicitly that include the capillary-pressures and the transmissibilities to each phase. The set of equations so obtained is solved implicitly for pressure with iterative updating of the pressure pressure with iterative updating of the pressure dependent terms. Having obtained the pressures, the saturations are computed directly from the water and/or oil flow equations. Iterative updating of the saturation dependent coefficients impairs the computing efficiency and the stability of the system. The implicit pressure entails simultaneous solution of N-equations for an N-grid-block system per iteration.
The IMPES procedure by virtue of its simplicity is amenable to a number of efficient matrix inversion techniques, and thus involves minimum computing time per time step. The explicit dating of the saturation dependent terms, however, imposes a conditional stability that limits the time steps to an impractically small size in many applications of interest. In particular, wellbore coning systems, the gas percolation and the water drainage problems, percolation and the water drainage problems, reservoirs with steep capillary-pressure slopes, etc. are difficult to simulate in the framework of IMPES, without resorting to artifices.

2. Simultaneous Solution Method (SS)
SS approach readily permits implicit treatment of the saturation dependent terms and offer a high computational stability.
An Underground Coal Gasification Experiment, Hanna, Wyoming
Authors: Schrider Leo A. , Jennings James W. 
Published: December 2007

Abstract
In the fall of 1972, the Bureau of Mines began an experiment to investigate the technologic, economic, and environmental considerations of underground gasification of a western subbituminous coal. The gasification site is near the town of Hanna, Wyoming, approximately 70 miles northwest of Laramie. The test results indicate that gas volumes and gas heating values have fluctuated over a wide range depending on operating conditions. The ranges have been from 50,000 to over three million standard cubic feet per day of produced gas with a composite heating value from 30 to 465 Btu per standard cubic foot. Even though these fluctuations have occurred, a semi-steady state condition existed for a six-month period. From September 1973 through February 1974 a low Btu gas averaging about 130 Btu per standard cubic foot was produced at an average rate of 1.6 million standard cubic feet per day. A material balance made during this period indicated:There was little or no underground gas leakage from the site;About 80 barrels of formation water were consumed each day;Between 13 and 46 tons of dry coal were affected each day depending on the assumptions made; andFrom 23 to 65 percent of the energy of the coal being subjected to carbonization and/or gasification is being recovered.
If the gas can be sustained at this relatively steady Btu content and production rate, it could be used directly to fire a boiler or to fuel a combined gas turbine-steam turbine cycle in electric power stations. The average amount of energy power stations. The average amount of energy produced from this small field test would have produced from this small field test would have been adequate to supply fuel for about a one megawatt power station.

Introduction
Interest in underground coal gasification has been stimulated recently by the Nation's growing energy demand. Its potential for generating plentiful supplies of fuel gas without the environmental disturbance of surface mining and without exposing workers to the hazards of underground coal mining is especially promising. While not expected to replace coal mining, it offers an alternative method of bringing the energy value of the coal to the surface. If feasible, this clean energy form could supplement the gas supply used to produce electricity, particularly in the industrial sector. It may also be possible to upgrade the gas to pipeline quality or to produce methanol as a possible substitute fuel for gasoline.
The role of oil and natural gas as sources of energy is almost as well known as the shortage of these vital fuels. More than three-fourths of the energy used in the United States in 1972 was derived from these sources. Coal, the most abundant fossil fuel, supplied only 17 percent of the Nation's energy needs in that year.
Molten Salt Processing Of Fuels
Authors: Cover A.E. , Schreiner W.C. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Molten alkali metal carbonates are catalysts for the gasification of hydrocarbonaceous fuels with steam. The gasification temperature can be varied by changing the melt composition so that a range of products can be made from fuel oil to substitute natural gas. Molten salt gasification can be used for processing of heavy oils and municipal processing of heavy oils and municipal refuse, for coal to SNG, clean power, clean boiler fuel, synthesis gas and ammonia. Heavy oil pyrolysis and cracking in molten salt are discussed in this paper. The status of development is given.

Introduction
The Kellogg Molten Salt Process under development for the past ten years has been aimed at coal gasification to produce a high Btu pipeline gas and a produce a high Btu pipeline gas and a low Btu boiler and gas turbine fuel. Progress on this process has been Progress on this process has been reported in various publications and is basically covered by U.S. patent 3,252,773, among others. However, initial interest at Kellogg was not for coal gasification but for heavy hydrocarbon conversion. The initial experimental work on this process was done in 1959 and is the subject of U.S. patent 3,252,774. The purpose of this patent 3,252,774. The purpose of this paper is to describe our work on the paper is to describe our work on the processing of heavy oils and to give the processing of heavy oils and to give the status of development of the molten salt process. process. PROCESSING OF HEAVY HYDROCARBONS PROCESSING OF HEAVY HYDROCARBONS It has been known for many years that alkali metal carbonates (lithium, sodium potassium) promote the carbonsteam and carbon-CO2 reactions. When equal parts of the above three alkali metal carbonates are mixed, an eutectic mixture is formed which melts at about 750 degrees F. This melting point then allows operation of a reactor point then allows operation of a reactor over a wide range of temperatures so that the products can be changed almost at will.
Shown in Figure 1 is the relationship between molten salt reactor temperature and the range of principal products when a heavy oil is the feed material. As seen in Figure 1 at 900–1000 degrees F, fuel oil, gasoline and lighter materials can be formed. At 1300–1500 degrees F, liquid products are no longer produced but ethylene-propylene are maximized.
Unitization and Additional Recovery Planning in the Jay-Little Escambia Creek Fields
Authors: Havenstrite J.J. , Hadlow R.E. , Harris R.W. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.

Abstract
Within four years of discovery, the Jay-Little Escambia Creek Field was producing over 90,000 BOPD and additional recovery operations had begun under unitized operations. This paper reports the planning investment commitments and unitization efforts that brought about these achievements in this important oil discovery.

Introduction
The deep sour Jurassic trend of northwest Florida and south Alabama has been an area of intense industry activity in recent years. Since June of 1968, over 400 million barrels of crude and condensate and over 600 billion cubic feet of gas have been discovered. This paper is concerned with the Jay-Little Escambia paper is concerned with the Jay-Little Escambia Creek Field (Jay-LEC) which is by far the most significant discovery in the area with crude reserves estimated to be about 340 million barrels. Within four years of discovery, this field was unitized and producing over 90,000 BOPD. Within four days of the effective date of unitization, waterflood-pressure maintenance operations had begun. These achievements are notable examples of the benefits that can result through careful planning, vigorous investment commitment, and cooperation among all the interested parties in an important oil discovery.
Development of the Jay-LEC Field reflected an aggressive and competitive investment commitment. The second confirmation well was a three mile stepout. Sour crude production was initiated under stringent regulations within 6 months of discovery by relocating and modifying a used gas treating facility. Initial steps to construct a pipeline with capacity in excess of 100,000 BPD were taken when the field was producing less than 10,000 BOPD. The working producing less than 10,000 BOPD. The working interest owners committed to over 90,000 BOPD in treating capacity and sulfur recovery equipment within two years of discovery and entered into purchase contracts that committed over $10 million for waterflood facilities prior to agreement on unitization plans.
Additional recovery studies were planned to support specific field development needs. Preliminary evidence indicated primary would Preliminary evidence indicated primary would be low and that injection would be necessary.
A Case of the Commercial Polymer Flooding Under the Complicated Reservoir Characteristics
Authors: Deng Zhizhan , Tang Jinxing , Xie Feng , He Jinsong 
Published: December 2007

Abstract
According to the reservoir characteristics of H2II zone in Xiaermen oilfield, where sandstone is unconsolidated, porous and highly permeable, and formation is severely heterogeneous, even large channels exist, and oil viscosity is relatively high, a combined EOR technology of ‘high strength in-depth profile modification with ultra high molecular weight polymer flooding’ is applied to a commercial polymer flooding project conducting in this oil zone, which would finally result in an increase in oil recovery efficiency by 10% OOIP. This paper introduces the design features of the technology and analyses the field performance and phase results of the project.
Mathematical Model Simulates Actual Well Conditions In Fracture Acidizing Treatment Design
Authors: Coulter A.W. , Alderman E.N. , Cloud J.E. , Crowe C.W. 
Published: December 2007

Abstract
A new mathematical model has been developed which considers more of the variables encountered during fracture acidizing treatments than previous models. In particular the variables include, wellbore cooldown, temperature profile of fluid in the fracture, the fracture geometry created by both non-reactive and reactive fluids the spending of the leading edge of the acid, and the conductivity of the etched fracture faces. Productivity increases calculated by the new program correlate more closely with actual field results than those calculated by previous programs. This paper describes the previous programs. This paper describes the method of handling the variables in setting up the new model and presents the equations used to describe the reaction rate of the acid.

Introduction
Fracture acidizing has been used for stimulating wells for over 25 years. The techniques used have developed more as an art, than a science, often based on intangible ideas, rather than on predictable facts. Although a mathematical model has been available since the early 1960's, little correlation has been observed between predicted and field results. One reason for this undoubtedly was due to the use of the acid as both the hydraulic fracturing fluid and as the reactive fluid. Another was the inadequacy of the model to describe the rheological and physical properties of the fluids in the fracture. properties of the fluids in the fracture. Only when treating techniques changed, in which better results were obtained by creating the fracture with a non-reactive pad fluid ahead of the acid, was serious effort directed toward describing the conditions or properties of the fluids in the fracture.
Equations were developed first to describe the cooldown of the wellbore area, as illustrated by Ramey's "Wellbore Heat Transmission" equations in the Appendix. Then, Whitsett and Dysart, and later Sinclair, proposed methods for describing the proposed methods for describing the temperature profile of fluids within a hydraulic fracture. Hall and Dollarhide provided basic equations for considering the fracture geometry created by more than one fluid within the fracture.