bluuebunny/crossref_metadata_2025_split huggingface dataset:
Review of the Completion Practices in the Wilcox Formation in South and South Central Texas
Authors: Garbis S. J. , Brown B. J. , Mauritz S. J. 
Published: December 2007

ABSTRACT
The Wilcox formation is a primary target for exploration and development of relatively low permeability tight gas reservoirs. Many operators have and will continue to drill for the Wilcox in South and South Central Texas. This formation continues to make a major economic contribution to the area's oil and gas industries. This paper will present background information on the geology of the Wilcox formation. The data presented will include lithology data derived from x-ray diffraction, and Scanning Electron Micrograph (S.E.M.) studies of whole core and/or sidewall core samples. The formation rock characteristics, such as permeability, porosity, youngs modulus, and formation water analysis are also discussed. Some of the latest completion techniques, including cementing, casing and perforating programs, are discussed in detail. Bottom hole pressure, thermal and fracture gradients are reviewed due to their important influence on completion practices.
A variety of stimulation procedures have been used very successfully on the Wilcox formations. Stimulation fluid selections, volumes and even injection rates have their influences on completion practices and resultant production. Finally, the types and size proppant selected and the volumes used are presented to maximize the production and to provide an optimum completion program.
Application of Pseudo-Steady-State Flow to Pressure-Buildup Analysis
Authors: Slider H.C. 
Published: December 2007

This paper was prepared for the Society of Petroleum Engineers Regional Meeting to be held in Amarillo, Tex., Oct. 27-28,1966. Permission to copy is restricted to an a 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
This report develops a method of analyzing pressure buildup data in a finite-acting reservoir and demonstrates the method with exemplifying calculations. It is believed that this method is, in most cases, superior to methods currently in use. Many engineers currently attempt to apply the Horner method of analysis, which is based entirely upon infinite-acting reservoir equations, to wells which have obviously been affected by the drainage limits of the reservoir and thus are finite-acting. Furthermore, the methods presently available for buildup analysis in a finite-acting reservoir are not as simple as the Horner method to apply and require a knowledge of the reservoir size, effective compressibility, effective formation thickness, porosity and fluid viscosity if the skin factor and average pressure are to be evaluated. In contrast, the method presented herein is very similar to the Horner method in that it requires similar pressure plots and uses similar equations; also, the formation capacity, the average drainage area pressure, and the skin factor can all be determined with a knowledge of only the fluid viscosity and the [re/rw] ratio. Even the Horner solution does not provide the skin factor with such limited data.
A solution based on such limited data is made possible by using the change in reservoir pressure prior to shut-in to determine the product of effective compressibility, porosity and effective formation thickness.
The application of pseudo-steady-state flow to pressure-buildup analysis is made Practical by an analytic derivation of the time when pseudo-steady-state flow begins. The development of these concepts, with a review of the basic pseudo-steady-state technology, is presented herein.

COMPARISON OF PSEUDO-STEADY-STATE FLOW WITH OTHER FLOW REGIMES
Reservoir fluid flow may be generally classified as steady-state, unsteady-state and pseudo-steady-state. This last classification, with which this report is concerned, has also been referred to as "stabilized") or as "steadystate in a bounded drainage area". This type of reservoir flow occurs much more frequently than steady-state flow or unsteady-state flow with an expanding drainage radius.
Understanding the Basics of Electrical Submersible Pump Performance
Authors: Wilson B. L. 
Published: December 2007

ABSTRACT
This paper is directed at the field engineer whose responsibility is to select a proper electrical submersible pump for a given well condition. This paper develops graphic representations of the demands placed on the pump, and shows how the major pump design parameters affect the pumpperformance. By understanding the basic conceptsin pump selection, the engineer will also be able to understand and predict the change in pump performance as well conditions change. This paperalso discusses methods of modifying pump performance of an installed ESP in order that the pump approach optimum pumping conditions and will review these techniques in light of their effects on the pump itself.
Feasibility Studies for Offshore Field Development
Authors: Williams L. M. 
Published: December 2007

ABSTRACT
Feasibility studies for development of offshore fields must satisfy both technical capability and economic success. To accomplish these objectives, feasibility studies are subdivided into a number of specific tasks to provide a systematic, sequential approach to developing an optimum design. The primary tasks to be performed are selectionof a project team, selection of criteria, description and evaluation of alternative concepts, preliminary design of the selected conceptual costingand economic evaluations. The method of approach to such studies, the requirements for each task and its objective are discussed.
Satellite Communications Change Drilling Operations and Procedures
Authors: Veenkant R. , Vitali J. D. 
Published: December 2007

ABSTRACT
This paper describes the Critical Drilling Facility (CDF) communications system design. Different field configurations for active and semi-active operations on the north slope of Alaska, in the Anschutz Ranch of Wyoming, and on semi-submersible drilling rigs in the Bering Sea will be discussed.
Historically, oil drilling has operated without any significant communications between the personnel at the rig and the experts and supervisors in regional headquarters. This is still standard practice in the drilling industry today. A drilling system based upon complete communications and team-work has been developed. It exploits the technologies of digital satellite communications, digital video bandwidth compression, drilling data sensor and computer systems, and real-time data transmission. Full-motion video of rig operations and personnel, facsimile, voice, forms entry and access, and drilling data transmissions are available. Also, real-time cementing and well-test data are available at CDF central for resident expert analysis.
The CDF not only supports real-time drilling decisions, but provides reproducible technology transfer for drilling future wells in the same field. Although the CDF was originally designed and implemented for drilling, it has become so successful that exploration geologists and managers are finding themselves right-there at the rig without leaving headquarters.
Semi-Submersible Used as Floating Production Facility
Authors: Hammett D. S. 
Published: December 2007

Abstract
This paper describes the technological achievements and experiences of utilizing a semisubmersible drilling unit as a floating production facility.
The technology of using floating production facilities, where fixed platforms are less economical to deplete small offshore fields, has been proven. Fifteen (15) semi-submersibles have now accumulated 100 rig years of experience producing and shipping oil from offshore fields. The semi-submersible rigs are used as floating production facilities to which subsea wells are connected by flowline and on the floating facility, the produced fluids are separated, treated and shipped. The floating facility installations are not temporary facilities, but are designed to fully deplete the fields. Gas lift, gas and water injection equipment are installed and in operation. The facility is designed to meet local and international safety codes and regulations.
The use of known technology to produce offshore fields utilizing Floating Production Facilities(FPF) will be extended to deplete reservoirs more economically than fixed platform development.
The conclusion of this paper presents the capability to utilize existing semi-submersible type hull forms to produce marginally economic fields that cannot justify conventional platforms installations.
The Role of Petrographic Analyses in the Design of Nondamaging Drilling, Completion, and Stimulation Programs
Authors: Kersey D. G. 
Published: December 2007

ABSTRACT
Petrographic techniques that include X-ray Diffraction, thin section, and Scanning Electron Microscope analyses can assess the potential reservoir sensitivity of a formation. The results of these analyses can be used to design programs to minimize formation damage from fresh-water and acid (HCl, HF) sensitive minerals and to reduce the severity of migration of "fines" and "sand" production problems.
Prevention of Undesirable Precipitates from Acid Treating Fluids
Authors: Crowe C. W. 
Published: December 2007

ABSTRACT
Precipitation of insoluble reaction products during the acid treatment of producing and injection wells is a problem which has long been recognized. These precipitates are capable of reducing the effectiveness of treatments or, in some cases, causing complete plugging of the formation. Among the precipitates which can form are iron compounds, such as ferric hydroxide and ferrous sulfide. When hydrofluoric acid is used, calcium fluoride, hydrated silica and various hexafluosilicates can precipitate. Acids also react with some crude oils to precipitate asphaltic sludges. An understanding of potential precipitates, conditions under which they form and methods of preventing or minimizing the problem is necessary to obtain optimum treatment results.
Precision Perforation Breakdown for More Effective Stimulation Jobs
Authors: Hushbeck D. F. 
Published: December 2007

ABSTRACT
Operating companies are using precision perforation breakdown techniques to help achieve stimulation of their complete perforated intervals. Special packers are used to isolate one ft (.3m) sections of the perforated interval, after which a small volume of acid is pumped into the formation to make an initial breakdown. The full stimulation treatment is performed through the breakdown tool without removing it from the well.
Several benefits accrue from the use of precision breakdown techniques:
Perforations are cleanedout and the formation is broken down slightly to give the treatment an opening to begin an acid treatment or a fracture. Status of perforations is established. If some of the perforations expected are not open, the job designer can alter his treatment to allow for fewer perforations. Pumping rates and pressures are sensitive to the number and diameter of perforations. Breakdown packers can be set many hundreds of time without maintenance during the breakdown, thus saving rig time. Limited entry stimulation is aided by detailed knowledge of perforation status. Scale buildup can be spotted directly with acid.
Subject paper presents field results, job designs, and engineering detail of breakdown packers. Application and operational details are presented.
Numerical Simulation of Light Oil Steamflooding in the Buena Vista Hills Field, California
Authors: Hong K. C. 
Published: December 2007

ABSTRACT
In early 1985 Chevron U.S.A. initiated a pilot steamflood of the light 27°API gravity (0.89-g/cm3) crude in the 108-ft (32.9-m) thick Wilhelm sand reservoir at the Buena Vista Hills Field in Kern County, California. The pilot project involves 12 inverted five-spot patterns over a 65-acre (263,000-m2) area with the target reservoir at an average depth of 2500 ft (762 m). A computer simulation study was performed to provide performance forecast and other information useful for the design, implementation, and operation of this first application of steamflooding to a light oil reservoir by Chevron.
A one-eighth of a five-spot, three-dimensional representation of the reservoir was simulated using a compositional steamflood simulator. The reservoir oil was represented by a three pseudo component model based on a true boiling point curve analysis of the crude.
The study showed that because of the low viscosity and high volatility of the oil, steamflooding this oil benefits from mechanisms different than those for a heavy oil. While oil viscosity reduction is the primary mechanism for production of a heavy oil, steam distillation is shown to be mainly responsible for improved production from the light oil reservoir. Whereas gravity override of steam prevails in a heavy oil reservoir, steam is seen to propagate in a more piston-like manner in the light oil reservoir, producing a more effective sweep of the reservoir. Also, the steamflooding in the low compressibility, light oil reservoir is characterized by an almost immediate production response to steam injection.
The study further showed that approximately 50% of the oil initially in place can be recovered economically by steamflooding. Over one-third of this recovery can be attributed to the steam distillation mechanism.
Production Optimization Using a Computerized Well Model
Authors: Lea J. F. , Brown K. E. 
Published: December 2007

Abstract
Many oil and gas wells may be producing at rates which appear to be optimum but which actually contain unnecessary restrictions to flow. These wells can be analyzed using modelling techniques to evaluate all components of a producing well system. Often this procedure will identify possible modifications in the well which if made will result in larger flow rates. This method described is often referred to as Nodal* Analysis. All components starting at the static reservoir pressure and ending at the separator are evaluated if present. This may include inflow performance, flow across the completion, flow up the tubing string including any downhole restrictions, safety valves, flow across the surface choke (if applicable) and flow through horizontal flow lines and into the separation facilities.
The objectives of well analysis are as follows: To determine the flow rate at which a well will produce with a given wellbore geometry and completion (first by natural flow).To determine under what flow conditions a well will cease to produce. This can be related to time as the reservoir depletes.To select the most economical time for the installation of artificial lift and to assist in the selection of the best artificial lift method.To optimize the well conditions and geometry system in order to most economically produce the objective flow rate.To analyze each component in the well system to determine if it is restricting the flow rate unnecessarily when compared to the flow capacities of the other system components.Overall, this permits quick recognition by the operator's management and engineering staff of ways and means to increase production rates. This is a very important feature of being able to graphically display the wells performance with "production optimization" or "Nodal* Analysis Techniques."
There are numerous oil and gas wells around the world that have not been optimized to achieve an objective rate in an efficient manner. In fact, many may have been routinely completed in a manner such that their maximum potential rate cannot be achieved. Also, many of the wells placed on artificial lift are not achieving the efficiency that may be possible.
Understanding Changing Wellbore Pressures Improves Sand Control Longevity
Authors: Stadalman J. R. , Novotny R. J. , Houchin L. R. 
Published: December 2007

ABSTRACT
A pressure surge in a gravel packed wellbore can cause the gravel to fluidize and move. This results in damage or complete failure of the gravel pack. Two solutions are presented for this problem. The first is to allow the pressure increase to occur only over an expanded time frame. This keeps the fluid velocity rising up through the gravel in the wellbore below the "Minimum Velocity Required for Fluidization" (Vo). In many cases the required time is impractical or control over the pressure surge and shut-in time is lacking. The second solution, a consolidated gravel pack, enables the gravel to be exposed to severe pressure surges and fluid velocities without fluidization occurring.
Acidizing Sandstone Formations: A Detailed Examination of Recent Experience
Authors: Gidley J. L. 
Published: December 2007

ABSTRACT
The purpose of this study was to determine how the response of sandstone formations is related to the individual components of acid treatments employed on them. Our goal was to identify the conditions that on the average lead to the greatest response. For this purpose, we collected detailed engineering data on stimulation treatments conducted within Exxon Company, U.S.A. over a three-year period, 1982–1984. During this period, more than 1,400 acid treatments were performed, of which 785 were on sandstone formations. Of the latter, 529 employed a mixture of hydrofluoric and hydrochloric acids. The response of wells treated with this formulation, commonly called mud acid, is the focus of the current study.
Mud acid, unlike hydrochloric acid alone, possesses the ability to dissolve clay materials. Its principal use in sandstone formations is to dissolve clays that have been affected by or are the result of the drilling or completion process. Such clays reduce formation permeability near the wellbore--a condition commonly called formation damage. The mechanism by which mud acid dissolves clays has been well described in the literature1–7 and is not the subject of the present work. Because of its high reactivity with clays, mud acid is spent relatively close to the wellbore (from a few inches to at most a foot or so from the sandface). Its sole value, therefore, is to remove damage near the wellbore.
Predictions of Water Floods by Graphs
Authors: Higgins R.V. , Boley D.W. , Leighton A.J. 
Published: December 2007

Abstract
In Part I, a method using relative permeability curves is presented to determine in about 30 min. by the use of a desk calculator and graphs the oil recovery vs cumulative water-injection of linear and 5-spot water floods. For the linear model the determinations are nearly identical to those calculated by the electronic computer used in the Higgins and Leighton technique,1 and for the 5-spot they are within an average of 2 per cent of them. The .5-spot results by the graphical method are also within an average of 5 per cent of those for presently available experimental 5-spot water floods. However, the graphical method does not give the time or rate of oil recovery.
The study shows that the recovery for the linear vs the 5-spot differs by only a small amount after about one displaceable volume is injected. This indicates that relative permeabilities are a more dominant factor in the recovery of viscous oils than pattern efficiency. This further indicates that the concept of "dead" areas in patterns is questionable. This method, with changes in the factors, is applicable to other patterns.
Part II contains material and relationships that are not as accurate as would be obtained by the electronic computer. Part II presents specific examples relating to the effect of pressure and free gas saturation on the viscosity of crude oil mixtures before and after the start of a water flood. A method to approximate the effects of initial free gas saturation and the effect of the absolute permeability variation with depth on the recovery of oil from a 5-spot water flood is also presented and illustrated.
Goal Setting and Federal Oil and Gas Leasing Policy
Authors: Zabler J. F. 
Published: December 2007

ABSTRACT
Since 1979, the Department of the Interior and Congress have considered changes in oil and gas leasing. Over this period there were changes in emphasis between program goals. In pursuit of these goals many leasing methodologies have been explored. This presentation elucidates each technique within the context of those goals and elaborate on the decision process of weighing the conflicting factors involved.
Current Status of Oil Industry Congressional Tax Reform Legislation
Authors: Gage G. H. 
Published: December 2007

ABSTRACT
"There doesn't seem to be any growing enthusiasm for this bill."
With characteristic understatement, Majority Leader Bob Dole described the prevailing attitude of the Senate towards tax reform, at a meeting of the National Governors' Association in Washington the end of February.
Nevertheless, the Finance Committee is continuing to gear up for a markup of the tax reform bill.
Wellsite Applications of Integrated MWD and Wellsite Data
Authors: Martin C. A. 
Published: December 2007

ABSTRACT
The advent of a wellsite computing center utilizing a common data base for surface and downhole measurements while drilling, provides new answers regarding safety, drilling efficiency and geological evaluation.
New applications have been developed utilizing the synergistic combination of measurements made at the surface during drilling coupled with MWD measurements. These applications have demonstrated significant improvements in drilling efficiency, geological evaluation and safety. On-line drilling programs have been developed to improve hydraulics, rate of penetration and solve drilling mechanics problems. Formation evaluation software provides an immediate indication of water saturation. Safety is enhanced by on-line plotting of pressure trends from MWD resistivity, formation strength analysis and other pressure parameters. In addition real time computer programs improve safety performance of the rig crew while tripping and while controlling kicks.
Computerized Drilling Jar Placement
Authors: Askew W. E. 
Published: December 2007

ABSTRACT
This paper presents information on a computer program currently in field use for determining optimum drilling jar positioning in Bottom Hole Assemblies. A finite element program models the BHA and predicts the force at the stuck point with the jar at various locations and tripping loads. Comparison of predicted impacts shows which position will produce the best response at the struck point increasing the chances of recovery.
Evaluation of Cementing Practices by Quantitative Radiotracer Measurements
Authors: Kline W. E. , Kocian E. M. , Smith W. E. 
Published: December 2007

ABSTRACT
A radiotracer technique has been developed that enables quantitative, foot-by-foot measurements of cement coverage behind casing. Based on uniform tagging of the entire cement column with short half life isotopes, this new technique enables measurements of cement placement, mud displacement, and the mixing that takes place at displacement fronts. The method was used in a study of cementing practices conducted in a series of East Texas wells. Radiotracer measurements were obtained that document cement coverage in wells drilled with 9-10 ppg (1080-1200 kg/m3) mud. Variables investigated include casing movement, casing attachments, and wellbore deviation.