bluuebunny/crossref_metadata_2025_split huggingface dataset:
Compensation for Borehole Effects and Porosity Determination With the Thermal Multigate Decay Log
Authors: Wyatt D. F. 
Published: December 2007

Abstract
The determination of reservoir porosity through casing has become a vital concern as more old fields undergo detailed re-evaluation. Many times the prevailing situation is that there is no reliable porosity data and the well has tubing in place. In such cases, pulsed neutron capture (PNC) logs are often relied on for both formation porosity and capture cross-section information.
Environmental effects on the pulsed neutron count rate ratio curve can be quite large and can have a dramatic effect on porosity calculations. This paper discusses the empirical modeling of typical downhole conditions that affect the TMD* ratio log and introduces updated corrections that can be applied to compensate for them. Included in the modeling are effects due to varying borehole fluid salinity, casing and tubing diameter, and cement. A lithology dependent ratio-to-porosity transform makes this conversion more consistent with density, neutron and acoustic techniques. When wellbore conditions are known, these computations can be applied either real-time or post-log at the wellsite to allow immediate reservoir evaluation.
Both test formation and field log data are presented to demonstrate the accuracy and utility of the environmental corrections and porosity transform.
Sucker-Rod Pump Diagnosis With Fluid Inertia Considerations
Authors: Csaszar A. B. , Laine R. E. , Keating J. F. , Jennings J. W. 
Published: December 2007

Abstract
Existing state-of-the-art diagnostic models neglect fluid inertia. Sometimes fluid inertia distorts the shape of the pump card. This is important because the shape of the pump card is used to diagnose the operating condition of the sucker rod pump, and to effectively monitor and maintain rod pumped wells. This paper presents guidelines for predicting when fluid inertia is likely to cause pump card distortion. This paper then discusses the equations, boundary conditions, and solution method for calculating fluid inertia forces and removing them from a calculated pump card.
Dynamic Behavior of the Sucker Rod String in the Inclined Well
Authors: Lukasiewicz S. A. 
Published: December 2007

Abstract
The paper presents a model for predicting and analysing the behaviour of sucker rod pumping installations in the inclined wells. This model incorporates the dynamics of the curved sucker rod string, and the friction forces resulting from the contact of the rod with the tubing through a system of two partial differential equations. This system of equations is solved by the finite difference technique. The model predicts the polished rod and pump dynamometer cards and incorporates the effects of fluid inertia and viscosity. The model is capable of simulating a wide variety of pump conditons, and geometry of the rod string. The examples and comparisons with the results obtained using a program for vertical wells to analyse the deviated well are presented. The information predicted by the model is useful in the design and operation of sucker rod pumping installations.
Application of a Pattern-Matching Expert System to Sucker-Rod, Dynamometer-Card Pattern Recognition
Authors: Keating J. F. , Laine R. E. , Jennings J. W. 
Published: December 2007

Abstract
Two expert systems distinguish between acceptable and abnormal operations; both utilize an established pattern recognition algorithm. Surface dynamometer cards for individual wells are used to check for normal operation. Surface cards can also provide feedback to pumpoff controllers and to variable speed drives. Calculated pump dynamometer cards are used to diagnose malfunctioning wells. These expert programs improve productivity by focusing attention on malfunctioning wells. The analysis could be part of a centralized operation with remote data acquisition and an automatic daily computer printout identifying malfunctions by well. Library maintenance involves communication between the day-to-day users, the repair shop and the expert.
A Single-Trip, Dual-Zone Gravel Pack System Successfully Gravel Packs Green Canyon Area Wells, Gulf of Mexico
Authors: Brannon D. H. , Harrison D. T. , Van Sickle E. W. 
Published: December 2007

Abstract
A system was designed for the Green Canyon 52 A Platform (Marquette Project) to gravel pack close proximity, dual zones in a single trip. The use of this single trip system resulted in significant time and cost savings when compared to similar conventional dual gravel packs performed on this platform.
This paper describes the equipment, the benefits and limitations of the system, a comparison of operations and associated time between a conventional dual and a single trip dual gravel pack, and the specific well parameters and field results.
A Reeled-Tubing Downhole Jet Cleaning System
Authors: Fowler S. H. 
Published: December 2007

Abstract
Operators having wells with increased water production, water flood projects, and geothermal wells are experiencing downhole scale buildup problems that can be quite severe. Production can become choked off, and in extreme cases, complete plugging of the tubulars can occur.
A total system approach has been developed to remove scales without removing or damaging the production tubing and casing. This method involves the use of high-pressure, polymer-enhanced, submerged fluid jets combined with reeled tubing equipment. This efficient system has proven significant cost reductions can be achieved compared to existing scale removal techniques.
Successful Cementing of the Horizontal In-Situ Combustion GRI/DOE: Rocky Mountain No. 1 Coal Seam Project
Authors: Daulton D. J. , Wiercinski G. M. 
Published: December 2007

Abstract
The requisite of zonal isolation in a highly deviated, ultra-high temperature wellbore placed extraordinary technical demands on slurry design and cementing operations. This paper documents: (1) the project criteria, (2) proposed ultra high temperature and conventional cement slurries, (3) testing considerations, (4) quality control steps, and (5) operational procedures taken to successfully cement six wells. These wells were a critical part of an evaluation process involving two of the foremost in-situ coal gasification techniques.
The Rocky Mountain #1 project tested the Hanna #1 Coal Seam near Hanna, Wyoming. A 100 day controlled burn took place to gather data. This information would allow comparison of two combustion techniques. A water quality control program was implemented postburn in order to ensure non-contamination of the aquifer. The efficiency and effectiveness of the Controlled Retraction Injection Point (CRIP) module was compared with the Extended Link Well (ELW) module. A program was developed to drill and cement to surface three wells in each of the burn and production patterns. The ELW process would require two shallow vertical cased and cemented injection wells. These vertical wells would intersect a medium radius to horizontal cased and cemented production well. The CRIP process required three cased and cemented wells. Two of the wells, medium radius to horizontal, were designed for injection and production purposes. The third well was used for ignition of the CRIP and initiation of the in-situ combustion process.
Hydraulic isolation of all the wells was confirmed by a lack of uncontrolled by-products at the surface, controlled accountability of tracer elements during the burn and good pressure test of the casing shoe. The results of the successful cementing of both the horizontal and the vertical wells contributed to the precise monitoring and comparison of the in-situ burn patterns. In addition, restoration and maintenance of the quality of the aquifer could be recorded for future projects.
Process Control of Slurry Density: Impact on Field Performance of Slurry Density
Authors: Hitt R. J. , Sherwood R. M. , Nelson E. B. , Poyet G. 
Published: December 2007

ABSTRACT
Before a cement job, cement system compositions are carefully designed in the laboratory at a given anticipated slurry density; however, during the job, significant density errors or fluctuations can occur, and the properties of the resulting cement system may differ dramatically from those observed in the laboratory. For this reason, the accuracy and precision of cement mixing in the field have been topics of concern for many years. In this paper, the design and operation of a newly developed computerized vortex cement mixing system, which provides excellent density control, is described. In addition, case histories are presented which demonstrate the accuracy and precision of the mixing system, and the successful transfer of laboratory cement system performance to the wellsite.
The Versatility of Silica Fume as an Oilwell Cement Admixture
Authors: Mueller D. T. , Dillenbeck R. L. 
Published: December 2007

ABSTRACT
Micropozzolan spheres, condensed from the vapors of a metallic silicon/ferrosilicon liquid, possess multifunctional applications in oilwell cements. Commonly available and cost-effective, this amorphous substance imparts significant improvements in the physical and mechanical properties of Portland cements. The practical utility of silica fume as an admixture is primarily attributable to its particle size, chemical composition, and reactivity. Composed largely of silicon dioxide (SiO2), silica fume has an average particle diameter of 0.1 μm (100 times finer than cement or fly ash) and yields a surface area on the order of 20 m2/g.
When silica fume was added to cements or cement/fly ash mixtures, several beneficial effects were noted: (1) the water consumptive nature of silica fume allows it to function as an extender and a pozzolan substitute for lightweight cements; (2) high water adsorption combined with an increased pozzolanic reactivity promotes enhanced compressive strengths; (3) the purity and solubility of the material makes it suitable for combating strength retrogression in cements at temperatures above 230°F (110°C); (4) permeability and alkali content of the set product are reduced, both desirous properties in a carbon dioxide (CO2) environment.
Field Experiments With Automatic Casing Swabs
Authors: Haynes C. D. , Miller T. C. 
Published: December 2007

ABSTRACT
This paper describes the development and field testing of an automatic casing swab in northeast Ohio. This swab, operating in Clinton sandstone wells to depths of 5000 feet (1523 m), demonstrated an ability to increase gas production, improve orifice meter chart configurations and reduce operating costs on existing wells. On new wells, its use in lieu of tubing plunger and beam pump-sucker rod pumping systems has resulted in lower capital cost and enhanced profitability.
Development of the swab tool is continuing, and results to date indicate this system ultimately will be used in many of the 2500 Beiden & Blake wells in the Appalachian Basin.
Reeled-Tubing Technology Accelerates Coalbed Methane Production In the Black Warrior Basin
Authors: Coats E. A. , Johnson K. J. 
Published: December 2007

ABSTRACT
Reeled tubing technology has proven to be beneficial in solving both economical and production problems in the Coal Bed Methane (CBM) industry of the Black Warrior Basin near Tuscaloosa, Alabama. The primary benefit from using reeled tubing technology is one of economics. Operators can now prepare CBM wells for production quicker than was previously possible.
CBM completions must be cemented, the well bore cleaned and zones selectively stimulated. Reeled tubing technology can be used in cleaning cement residue from the casing ID and in cleaning frac sand, frac balls and perforating debris from the wellbore. Isolation bridge plugs can be retrieved and debris washed from the well. Five hundred wells have been cleaned of unwanted cement residue using high pressure submerged fluid jets and in excess of two thousand wireline-set retrievable bridge plugs have been retrieved using reeled tubing technology in the Black Warrior Basin.
Cost-Effective Completion Design for Offshore Oil Wells in Nigeria
Authors: Murphy S. S. , Nwankwo A. S. 
Published: December 2007

ABSTRACT
Oil companies have been forced to become more efficient and try new ideas to remain competitive in today's economic environment. This involves re-evaluating the cost effectiveness of tubing and downhole equipment designs and trying innovative ideas that have potential for significant cost savings.
This paper tells how Mobil Producing Nigeria (MPN), operator of the Joint Venture between MPN and the Nigerian National Petroleum Corporation (NNPC), reduced completion costs as a result of efficient tubing design. Tubing and thread design are discussed in detail and statistical tubing data is presented to show the need for thread standardization. Gravel pack and other downhole equipment designs are discussed in detail with case histories presented. Emphasis is placed on elimination of unnecessary downhole equipment and considerations for future fishing operations.
This paper also discusses in detail innovative ideas that reduced workover and completion costs during the last 24 months. These include:
A plugback completion design within the same reservoir that allowed the lower part of the interval to be isolated when cased hole logs were questionable. Innovative use of a joint of tubing to retrieve lost washpipe. A gravel packed open hole completion through a milled window in an inadvertently sidetracked hole. The milled window was the original completion interval prior to the workover. Innovative use of the cementing unit to free a stuck gravel pack crossover tool.
Rate Behavior of Composite Dual-Porosity Reservoirs
Authors: Olarewaju J. S. , Lee W. J. 
Published: December 2007

ABSTRACT
The main objective of this paper is to present a mathematical model of vugular or naturally fractured reservoirs with a radial discontinuity around the wellbore. This type of reservoir configuration is encountered in wells that are damaged, acidized, gravel-packed, or stimulated by cyclic steam soaking. This model is useful in predicting production performance or analyzing production data from these types of well-reservoir systems.
Small-Volume Sampling Technique Brings Economy and Efficiency to Well Testing Operations
Authors: Schultz R. L. , Breaux M. J. 
Published: December 2007

Abstract
A Small Volume Sampling Technique (SVST) allows operators to perforate, record temperature and pressure, and collect a formation sample prior to or in lieu of a well test efficiently and economically. Using this method, formations can be tested on a preliminary basis without the logistical burden of a comprehensive well test. Because of its economy, the SVST can also be used to test zones that were bypassed in older wells when expected production was not considered worth the expense of a comprehensive well test. The test apparatus is run in on drill pipe or tubing. Test procedure consists of perforation (usually about a 2 ft. interval)collection of a preliminary sample to allow formation cleanupcollection of a second sample (one to two barrels) in a chamber that also houses quartz-based electronic temperature and pressure recorders and small PVT samplers.
Collection of two samples also yields valuable drawdown and pressure buildup data from two flow periods and two closed-in periods. After the tool is retrieved to the surface, an approximate liquid-gas ratio and water cut can be determined while the sample is drained. PVT analysis is then performed in the lab on samples taken by the small PVT samplers.
A Management Planning Tool for Optimizing Use of Manpower and Equipment Resources
Authors: Welsch James W. , Hobbs N.M. , Alanis Rene E. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
This paper was prepared for the 43rd Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Houston, Tex., Sept. 29-Oct. 2, 1968. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made. provided agreement to give proper credit is made. Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office. Such discussion may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
An application of the computer as a management tool to aid in optimizing manpower and equipment resources is presented. The computer is used in the coordination of a large number of periodically recurring job functions to assemble, process and compile the various functions on the basis of priority, timing, accounting function, manpower and skill type requirements.
In the application described the computer is used to store, and retrieve pertinent information relative to the testing needs of several thousand gas wells. A properly designed computer system provides managers with ready accessability to tailored test schedules for each well. This allows periodic review of the demands on personnel and equipment with minimum effort. The ability to retrieve current information in several ways permits flexibility in analyzing changing situations. The application of the computer to this and similar problems also aids managers to satisfy work requirements in a timely manner.

Introduction
One of a managers primary functions is to efficiently coordinate manpower and equipment resources under his supervision. The problems associated with this management responsibility are compounded when the resources are spread over large geographical areas and engaged in a multitude of different activities.
This paper presents an application of the electronic computer as a management tool. The application discussed involves the coordination of well testing activities on sever thousand gas wells annually. The large number of wells, at various sages of depletion, and the resulting variations in testing needs create a multitude of activities which must be coordinated. To efficiently coordinate such a large number of activities manually is impossible. The computer, however, affords a tool with which a manager can rapidly assemble and compile the required job functions to aid him in discharging his responsibilities in a more prudent manner.
The Use of Acrolein as a Hydrogen Sulfide Scavenger in Multiphase Production
Authors: Howell J. J. , Ward M. B. 
Published: December 2007

ABSTRACT
The efficient reduction and removal of hydrogen sulfide (H2S) from produced fluids is an important technology that can have great impact on oil and gas operations. Hydrogen Sulfide is increasing in many production streams as water content rises. Not only can the export of gas be halted if H2S reaches too high a level, but employee safety and the environment are also influenced by rising H2S concentrations. In colder climates such as Alaska, facilities are predominantly enclosed which necessitates careful monitoring of H2S to maximize personnel safety. Burning of produced gas as fuel creates sulfur dioxide which is under strictly enforced limits. One of the more operationally attractive ways of minimizing H2S is via the addition of chemical scavengers directly to production containing oil, water, and gas. Acrolein (2-propenal) is evaluated in this manner on the North Slope. Although the sulfide scavenging ability of acrolein is well known to some production companies, this product has not been previously evaluated in North Slope operations. The results from a field test indicate that acrolein scavenges H2S rapidly at a low treating ratio. Approximately 65% of the total H2S was removed in less than two minutes from the production stream of one producing well making water, oil and gas, at a 1:1 molar ratio of acrolein:H2S. From the same wellhead injection point, it is further demonstrated that additional downstream production entering the pipeline system can be effectively treated. Reaction byproducts are completely soluble and stable, there are no stream upsets, and no acrolein residuals are detected downstream.
Evaluation of Paraffin Deposition Potential Using Drillstem Test Fluids
Authors: Santamaria M. M. , Roberts R. B. , Gill S. K. J. 
Published: December 2007

ABSTRACT
A laboratory study was conducted to determine the potential for paraffin deposition for three oils from offshore Angola discovery fields using drill stem test fluids. Additional tests were conducted to select an effective paraffin inhibitor and determine the appropriate chemical dosage.
Using the test results, the engineering design group planned for storage and injection of the chemical and pigging for the flowlines and pipelines.
The proposed paraffin control measures were implemented as the fields were brought on production. Coordination and planning by personnel from drilling, producing, engineering and the laboratory allowed implementation of an effective paraffin control program from the start-up of production.
Increased Breaker Concentration in Fracturing Fluids Results in Improved Gas Well Performance
Authors: Elbel J. , Gulbis J. , King M. T. , Maniere J. 
Published: December 2007

ABSTRACT
Conductivity damage resulting from fracturing fluids has been frequently observed in laboratory tests and is often indicated by production results. Abnormally high breaker concentrations were used in a number of fracturing treatments of gas reservoirs in attempts to minimize proppant conductivity damage and improve well performance. Concentrations of breaker of up to 10 lb/1,000 gal (three to five times the normal concentration) were added to fluids without causing premature loss of viscosity. These concentrations were made possible by encapsulating the breaker with a water-barrier coating and properly scheduling the breaker addition. The breaker addition schedule was optimized to account for the increasing polymer concentrations due to fluid loss as well as the fluid exposure time at the maximum temperature.
Improved well performance has been seen when using higher than normal breaker concentrations. The improved performance includes higher production rates. It can be shown that all of these results can be attributed to higher fracture conductivity because of the reduction of proppant conductivity damage.