bluuebunny/crossref_metadata_2025_split huggingface dataset:
Performance Evaluation of the MOCO T In-Situ Combustion Project, Midway-Sunset Field
Authors: Curtis J. H. 
Published: December 2007

ABSTRACT
This paper describes the analytical methodology applied to the MOCO T reservoir to match 27 years of dry in situ combustion project performance. It also serves to update previous technical papers on the project.
A modification of the Nelson-McNiel Analytical model is introduced that provides excellent agreement with field performance. The correlating factor derived is found to be strongly dependent upon the product of the air requirements and volume burned. Equations and graphical relationships are developed to show the recovery effects of various parameters such as air injected and volume burned.
The calculated combustion front location also agrees well with produced fluid temperature maps. Close agreement between the calculated burned thicknesses and those obtained from recent seismic tomography efforts is also presented.
The paper provides excess air, air-oil ratio, and oil-water ratio calculations as well as numerous graphical relationships that aided in an understanding of the reservoir, and may further improve process efficiency.
These results demonstrate that analytical methods can be applied successfully to history match and predict future performance. It is believed that these results have direct applications to other reservoirs with similar parameters and characteristics.
Validity and Accuracy of Reservoir Simulation With A Two-Dimensional, Three-Phase, Unsteady-State Heterogeneous Matrix Computer Model
Authors: Garrett J.E. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 42nd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Tex., Oct. 1–4, 1967. 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 validity and accuracy of reservoir simulation with the use of a grid-type numeric model employing explicit-computational procedures is demonstrated. In five separate areas of reservoir engineering technology, comparisons are made between the results of this model and those obtained by means previously adopted by the industry. In all cases, the model's answers compared favorably; in fact, in most cases its accuracy exceeded practical data limitations.
The conclusions reached are that [1] valid solutions can be obtained to a wide range of realistic reservoir problems by judicious use of these models; [2] the accuracy of the explicit-type model used in these tests is well within acceptable engineering tolerances; and [3] such models should obtain good, valid solutions to reservoir situations too complex to be handled by other available means.

Introduction
The latest engineering tool for the advanced study of reservoir performance is the grid or matrix type of numeric reservoir simulation model. By viewing the heterogeneous reservoir as many small homogeneous blocks or cells having different properties, such models are intended to permit accurate analysis of complex reservoir situations of essentially any type.
In recent papers, questions have been raised concerning the relative accuracy of the implicit and explicit pressure solution techniques used in these computer models. Of more value to the engineer, however, is the testing of the accuracy and validity of such models by comparisons with theoretical solutions or with proven analytical procedures to determine their worth, per se, as an engineering tool.
Optimization of Hydraulic Fracturing Treatments Applying Post-Fracture Pressure Analysis for the Upper Clearfork Formation
Authors: Rogers J. D. 
Published: December 2007

ABSTRACT
The technology developed for massive hydraulic fracturing in tight gas reservoirs is applied to create short, highly conductive fractures in the oil productive Upper Clearfork formation of West Texas. The contents of this paper review operational aspects of design and factors influencing the successful execution of fracture treatments during an extensive infill drilling and waterflood expansion program in the Amoco operated Prentice Northeast Unit (PNEU). The PNEU is located in Terry and Yoakum counties of West Texas.
Long Spaced Digital Sonic Log Data (LSDS) was collected on several wells in the Prentice Northeast Unit. This data, along with results of pump-in/flowback and mini-frac tests were used in conjunction with fracture design and economic models to develop an optimum fracture design for this reservoir. Fracture pressure analysis and post fracture pressure decline analysis techniques were used to further refine the optimum treatment design. The optimum fracture design, developed in this manner, was then used to stimulate over 60 wells in this Unit and other Amoco operated Units producing from the Upper Clearfork formation. Results of these fracture stimulations have been excellent.
This paper presents a discussion of the collection of post-fracture pressure decline data, the analysis of this data, and the application to optimize the design of hydraulic fractures in the Upper Clearfork formation. Fracture stimulation design is presented with a framework in which maximization of return on the invested dollar is the ultimate goal.,
Methods to Improve the Efficiency of Rod-Drawn Subsurface Pumps
Authors: Cox B. R. , Williams B. J. 
Published: December 2007

ABSTRACT
A modified sub-surface pump is presented with improved gas handling characteristics, and with the ability to flush sand and small particulate matter away from the leading edge of the plunger. The pump design utilizes a tubular hollow valve rod and precision sizing of the guide to create a low pressure chamber above the plunger on the down-stroke.
The two stage gas and sand check valve installed at the top open cage reduces buckling tendency on long stroke down-hole pumps, and actually eliminates the buckling on shorter strokes and shallow wells.
Buckling of valve rods is discussed and a method cf calculating the buckle point for the various plunger and valve rod sizes, and the longer stroke lengths are presented.
The modified hollow valve rod pump with the two stage gas and sand check valve has actually performed in high gas-oil ratio rod pumped wells, under a packer. Brief case histories are discussed in support of the application of this pump to wells where total fluid is produced through the pump.
A review of the basic API pumps with design advantages and disadvantages in down-hole conditions is given. Accessory items to help the basic pumps in handling gas-sand and corrosion are reviewed. These are economical devices, proven over a period of years, that can be readily applied to standard sub-surface pumps.
Theory of Paleozoic Oil and Gas Accumulation In the Big Horn Basin, Wyoming
Authors: Stone D.S. 
Published: December 2007

This paper, to be presented at the 42nd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, Houston, Tex., Oct. 1–4, 1967, is copyrighted by the American Association of Petroleum Geologists and will appear in the AAPG Bulletin. Permission to publish any portion of it must be obtained from the Publications Manager of that bulletin. SPE wishes to express appreciation for permission to preprint this paper, and to include it on the program.

Abstract
A theory of oil and gas accumulation has been developed to account for the relations among stratigraphy, structure and fluid distribution in the oil fields that produce from Paleozoic reservoirs in the Big Horn basin of Wyoming. This proposed theory related the common oil-water contacts observed in the normal multi-zoned Paleozoic anticlinal fields to height of the oil column, formational thicknesses in the crestal area, and number of Paleozoic formations productive of hydrocarbons in each field. The similar chemical composition of the Paleozoic crude oils, and of the associated formation waters, the vertical density stratification of fluids in the multizoned fields with large oil columns, and some unusual reservoir pressure relationships are cited in support of the concept of a common pool state.
The major conclusion of this study is that essentially all of the hydrocarbons held in Paleozoic and Triassic reservoir rocks in the Big Horn basin were generated from the euxinic, dark-colored, organic-rich and phosphatic, finegrained sediments of the marine facies of the Permian Phosphoria formation. Primary migration was probably completed by Early Jurassic time when these hydrocarbons accumulated within regional stratigraphic traps created primarily by updip facies change, pinchout and truncation of the reservoir carbonates of the Phosphoria formation, and also by uneven Phosphoria-Goose Egg truncation of the underlying Tensleep sandstone both locally within the Big Horn basin and further east in the area beyond that was covered by marine Phosphoria rocks.
The hydrocarbons held within these Phosphoria and Tensleep stratigraphic traps were later released as a consequence of fracturing and faulting associated with Laramide folding, and moved into older Paleozoic reservoir rocks until fully adjusted to anticlinal structure in common pools. Vertical segregation of an original common pool into several separate pools was accomplished in some exceptional fields of the basin either by selective hydrodynamic tilting within the Tensleep zone, by leakage or redistribution of fluids through fault zones, or by escape of hydrocarbons to the surface and inspissation resulting from breaching of the original Triassic cap rocks.
Tubing Conveyed Perforating Sucker Rod Pumping Wells
Authors: Holloway M. L. , Wesson D. S. 
Published: December 2007

ABSTRACT
During the development of the San Francisco field near Neiva, Colombia, South America, significant reductions in productivity indexes were encountered when wells were put on artificial lift after being perforated. These wells were completed in the Caballos formations, which typically span over 400 gross ft with 110 ft of net pay and appear to become damaged when exposed to water. Tubing conveyed perforating is the preferred technique due to its advantage of better inflow performance. When retrieving the tubing conveyed guns, aqueous control fluids were used to control some wells prior to running a sucker rod pump. Thus, these high volume wells usually suffered an increase in formation damage which lowered their productivity indexes.
A workable solution to this problem was developed and called a seating nipple bypass assembly. This tool enables conventional tubing conveyed perforating guns and a differential firing head to be attached to the bottom of a tubing string. The tool also contains an 3-½ in. API seating nipple so that a rod pump can be seated and operational when the guns are activated. Thus, a well can be completed with the benefits of using tubing conveyed perforating and immediately commence artificial lift. This achieves greater production rates without damaging the producing formation, as could have happened when controlling the well with aqueous based fluid while reconfiguring the bottom hole assembly.
Spreadsheet-Based Program Helps Solve Variety of Operational Problems
Authors: Hall J. W. , Andrew J. H. 
Published: December 2007

ABSTRACT
A microcomputer spreadsheet-based program has been developed to provide guidelines for dealing with common operating problems right at the wellhead. The spreadsheet uses basic daily production data to establish well-by-well production priorities. These priorities are clearly communicated in a format that eliminates guesswork and inaccurate assumptions and facilitates efficient responses to production upsets. Rapid response to producing problems helps reduce production losses and increases total revenue.
The Theory and Economics of Electrostatic Treaters
Authors: Cummings C. B. , Engelman C. E. 
Published: December 2007

ABSTRACT
Crude oil is rarely produced without some water being present. The water cut in produced fluids from the formation can vary from 0-99%. Most crude purchasers limit the amount of water and impurities that may be included with the oil, typically between 0.2% and 2.0%. The producer must separate the well fluids in order to sell the oil and dispose of the basic sediments and water (BS&W). Emulsified oil and water mixtures require treating to achieve an acceptable level of BS&W content. Heat, chemicals and electricity can be used to break the emulsions in an efficient and expedient manner. Due to lower treating temperatures, electrostatic treaters are often an economical means of dehydrating crude oil, but many times the advantages of electrostatics are overlooked. This paper discusses the basic process and economics involved with treating oilfield emulsions with electrostatics.
Case History Studies: Abnormal Pressured Gas Reservoirs
Authors: Poston S. W. , Chen H. Y. 
Published: December 2007

SUMMARY
Analysis of geopressured gas reservoirs often times is particularly difficult. The effects of pore volume compressibility as well as the uncertain presence of water influx should usually be included in the calculation procedures. The solution plot method is a straight forward procedure which negates the need for estimating these two troublesome reservoir parameters.
Computer simulation studies have shown variable pore volume compressibility effects exhibited by under-stressed, abnormally pressured gas reservoirs are based on grain expansion as well as pore collapse values. Normally compacted geopressured, gas reservoirs will display uniform pore volume compressibility effects.
The solution plot method permits the simultaneous estimation of the original gas in place, pore volume compressibility values as well as a qualitative estimate of the affect of water influx.
Case History of Restimulations in Western Oklahoma
Authors: Ennis B. K. 
Published: December 2007

Abstract
This paper presents the results of a restimulation workover program performed in Western Oklahoma during the last two years. The restimulations were selected from wells which were not producing at peak rates based on log development and post-frac pressure buildup tests.
The restimulation workovers have generated sufficient incremental cash flow to payout the entire program in eight months. Pre-workover and post-workover production rates in conjunction with workover costs are presented to justify the economics for the restimulations.
Laboratory, Computer Modeling, and Field Studies of the Pulse Fracturing Process
Authors: Schatz J. F. , Zeigler B. J. , Hanson J. M. , Christianson M. C. , Bellman R. A. 
Published: December 2007

ABSTRACT
A combined testing and modeling program has been completed with the purpose of providing systematic observations and models of the pulse fracturing process. Approximately eighty individual laboratory tests have been successfully carried out in blocks of scaled rock simulant loaded to a true three-dimension stress state with miniature propellant/explosive charges in a wellbore as the fracturing energy source. Real-time borehole pulse pressure measurements were also obtained. Mathematical models developed include descriptions of borehole pressurization, flaw initiation, gas-driven fracture propagation, and fracture arrest. Measurable material and natural parameters such as moduli, gas permeability, and in situ stress are used in the models. Models include true crack-crack interaction. One of the models is fully two-dimensional and includes fracture curvature in an anisotropic stress field. Results indicate that multiple fractures are created over a broader range of source, material, and natural conditions than had commonly been thought before, but that the conditions conducive to extremely long fracture extension, usually considered desirable, are somewhat difficult to establish and maintain. Several approaches to optimizing and evaluating the process in the field are suggested, including a possible approach to the generation of long fractures. A field test observation is described.
New and Unusual Applications for Plunger Lift System
Authors: Beauregard E. , Morrow S. 
Published: December 2007

ABSTRACT
As plunger systems become more sophisticated and people become more familiar with them, their credibility and usage is increasing. As a consequence, the spectrum of applications for these systems has begun to increase.
In the ongoing pursuit of lower lifting costs and reduced capital spending, creative engineering techniques have applied the principle of the plunger to some unique production problems. The purpose of this paper is to present a number of these along with some case histories.
The normal applications for a plunger are for Gas Wells, Hi-Ratio Oil Wells, Intermittent Gas Lift and Paraffin Removal.
Now, however, plungers are also being used to:
Produce liquids in extremely low pressure reservoirs Produce liquids in retrograde condensate wells Remove water from coal seam methane gas wells Prevent paraffin buildup in dual zone wells Prevent paraffin buildup and increase lift efficiency in deviated gas lift wells with wide perforated zones Remove liquids from wells with no tubing Prevent down hole freezing problems in high pressure gas wells Remove water from wells in CO2 injected formations
Another application that appears to be highly probable is liquid removal from CO2 source wells.
The major obstacle to more widespread utilization of plungers has been a lack of education. This has been a problem not only with operational personnel, but engineering and management as well.
Hopefully, these additional applications along with the present increase in usage will make people even more cognizant of the potential savings offered by the plunger lift system.
AL: An Expert System for Selecting the Optimal Pumping Method
Authors: Heinze L. R. , Thornsberry K. , Witt L. D. 
Published: December 2007

ABSTRACT
AL (Artificial Lift) is a software program for selecting the pumping processes best suited to an oil well. It integrates an expert system which manages the knowledge of the subject and organizes the implementation of a set of algorithmic programs for making technical assessments. AL was developed at the University of Missouri-Rolla, Petroleum Engineering Department. This article describes in detail the expert-system part and gives an example of the use of the complete system.
Root Locus Stability Analysis of a Flowing Oilwell Feedback Controller
Authors: Blick E. F. , Nelson A. B. 
Published: December 2007

ABSTRACT
Some naturally flowing oil wells will experience flow instabilities (heading) characterized by regular or irregular cyclic variations in tubing pressure and flow rate. To analyze this phenomena, the unsteady equations of motion for flow are solved by the LaPlace Transform method. This analysis produces a characteristic equation whose coefficients allow one to determine if a particular well is stable or unstable. If the well is unstable it is possible to use a feedback controller which varies the tubing head choke diameter to stabilize the well. By use of the root locus method, various combinations of proportional, derivative and integral controllers are shown to theoretically control some unstable wells.
Gas Turbine Driven Centrifugal Pumps for High Pressure Water Injection
Authors: Neal J.C. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 42nd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Tex., Oct. 1–4, 1967. 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 experience of Gulf Oil Corp. in the installation and operation of gas turbines as prime movers for centrifugal pumps in high pressure water injection leads to the following conclusions:
Installation of gas turbines and centrifugal pumps can be made with very little difficulty. Only a fraction of the foundation is required for this type of installation as compared with other types using heavier equipment. Vibration of equipment and piping is practically eliminated. It is felt that where low cost gas is available, two-shaft gas turbines driving centrifugal pumps are an economical and flexible high pressure water injection installation. Centrifugal pumps normally require less attendance than plunger pumps. Station construction costs compare favorably with other stations utilizing different types of prime movers and pumps. Centrifugal pumps can be designed for almost any condition of high pressure water injection, but there are certain conditions in which plunger pumps are more economical. When the volumes are low and the head high, plunger pumps are usually more economical. Gas turbines are easily automated for unattended operation. Several operating problems were experienced, but subsequent modifications now have provided for a highly satisfactory operation. Fuel consumption compares favorably with that of other types of gas engines. Maintenance and repair cost of the pump has been much lower than anticipated and gas turbine costs have been slightly higher than originally anticipated. The over-all operation is economically attractive.

Introduction
Four gas turbine engines are driving multistage centrifugal pumps for injection of high pressure water into Gulf Oil Corp's Goldsmith 5600' field, Ector County, Tex.
A Generalized Approach for Analyzing the Early-Time Pressure Transient Data
Authors: Duong A. N. , McLauchlin L. A. 
Published: December 2007

ABSTRACT
This paper describes a computer-aided interpretation approach that can be used to analyze the early time data of a transient test with wellbore storage and skin effects. Pressure derivative, pressure response and pressure cumulative are used to rearrange the convolution integrals into a linear relation of three variables. The coefficients of this relation are related to the model parameters of reservoir properties, wellbore storage constant and skin factor. A linear multiple regression is performed for these variables to obtain the optimal values for the model parameters. Once the model parameters are known, the calculation of pressure change can be performed for each flow regime assumed. The statistical and graphic analyses will be used to check the results, as well as the accuracy, of each flow regime assumed. This approach is simple. However, it requires that the reservoir response function does not change and the model parameters are constant during the analyzed period.
The advantages of this computer-aided interpretation approach are that the early time data can be analyzed numerically and the approach can be applied for any type of flow regime; i.e, radial, linear, bilinear and spherical flow.
A real data example is used to demonstrate the application of the proposed approach.