bluuebunny/crossref_metadata_2025_split huggingface dataset:
Demonstration and Teaching of Kick Control Techniques Using Microcomputer Graphics
Authors: Whitman D. L. , Evers J. F. 
Published: December 2007

Abstract
An inexpensive computer program, utilizing the graphical capability of the IBM-PC, has been developed that demonstrates and teaches the control procedures to be used as the result of a gas kick taken during drilling. In order to properly diagnose and control a kick, one must have a complete understanding of what is happening downhole and why. The color simulation that is presented in this paper – which can be run in real-time or accelerated time – aids in this understanding process. The status of the drilling process, as well as the critical surface measurements available, are displayed graphically on the screen before, after, and during the control of the kick. The display shows the gas bubble, its growth as it is circulated out of the hole, locations of all of the different fluids that are involved in the system (drilling mud, kill mud, and gas bubble), and the surface effects that occur during the control procedure.
The program can be run in either a demonstration mode or a control mode. In the demonstration mode, a kick is circulated out by the computer by both the driller's and the wait and weight methods, using the ideal control procedure. An instructor can utilize the demonstration to point out particular points of interest during the process. In the control mode, the operator of the program uses the keyboard to control the process. That is, he or she has direct control of the mud weight to be pumped, choke opening, and pump speed. At the conclusion of a run in either mode, graphs are produced of various pressures as functions of the number of strokes pumped.
In the control mode, the program monitors the correctness of the control scheme and highlights incorrect procedures that would result in either a low bottom hole pressure, causing a secondary kick, or a high pressure at the bottom of the casing, causing a loss of circulation.
Computer Database Program Provides Drilling MUD System Analysis at Rigsite
Authors: Morton E. K. 
Published: December 2007

Abstract
Microcomputers are becoming more prevalent on drilling rigs as a means of monitoring drilling parameters and doing repetitive calculations. Until recently, little, if any software was dictated to drilling mud property analysis that could easily be run on a personal computer on the rig.
A database has been developed that uses an inexpensive commercial software package allowing the user at the rig to input the daily mud properties and treatments. The software package allows the user to design the database to meet any particular situation that he requires. After he has made all of the inputs, all necessary calculations are then performed and a daily drilling mud report can be generated. Along with this package is the ability to instantly produce a graph of any set of properties or calculated values and view this either on the screen or on a printer. Trend lines for a certain property can be established and divergence from this trend line can quickly be noted. Adjustments in mud treatments could then be initiated.
Drilling fluid post well audits and recaps can now be generated as soon as the well is completed as all of the information is stored in the database. In this manner, the mud engineer enters the data at the rig and then this data can be sent to any location by modem or by floppy disk. This alleviates hand written reports that will have to be retyped by a secretary. The information only has to be entered once.
This system has been tested on several field jobs at the present with good results. Also, the program is user friendly and no intensive operator training is required. Input of data is very efficient and can be done in less than 15 minutes. A total drilling mud history for a well can easily be stored on a floppy disk and recalled for any post well analysis or future planning.
Computer Applications in the Planning and Drilling of a 2,000-ft Horizontal Well in Wayne County, West Virginia
Authors: Overbey W. K. , Carden R. S. , Williams J. B. 
Published: December 2007

Abstract
A personal computer with commercially available software was utilized in the planning and drilling of a 2,000 foot horizontal well drilled in the Devonian Shale in Wayne County, West Virginia. Planning procedures, well design and simulations of drilling operations were conducted with the software to identify potential problems and determine the size of rig required for the operation. Drilling progress was monitored with the computer as well as costs of drilling operations. Utilization of the computer was a key factor contributing to the successful drilling operations.
Microcomputer Program Aids for Cyclic Steam Injection Design
Authors: Chu M. H. , Gustafson S. J. 
Published: December 2007

ABSTRACT
A microcomputer program has been developed for use by engineers involved in the design of cyclic steam injection heavy oil processes using a microcomputer. In this program the economic model can be used on either a before or after federal income tax basis. The output data, such as incremental oil production and incremental profit over the unstimulated process, will help engineers evaluate prospective cyclic steam injection projects and make quick investment decisions.
Sand Stability Predictions on a Microcomputer
Authors: Yassin A. A. Md , Peden J. 
Published: December 2007

ABSTRACT
In planning for the production of oil and/or gas from the reservoir that consist of some form of sandstone matrix, consideration must be given as to whether a given well will remain sand-free during its productive life or if failure is to be expected. If failure is forseen, the prediction of the time of failure will allow a timely decision on selecting a suitable sand exclusion technique to be applied hence avoiding costly remedial treatment.
A prediction model was developed on a microcomputer to predict sand stability in a friable sandstone formation from stress-strain analyses around a perforated wellbore. Failure or instability of the formation around the wellbore was studies in terms of a failure initiation (initial failure).
Application of the model present here in includes the modes of failure around the wellbore, the prediction of the maximum allowable sand free production rate for a give well condition and sensitivity analyses of the factors controlling the production of sand from friable formations.
ISIS: A PC Interface and a Mainframe SQL Data Base
Authors: Snow E. L. 
Published: December 2007

ABSTRACT
An opportunity to reduce surveillance costs and to improve surveillance results was identified within Shell Oil Company's Production Department by implementing a modern production data handling system. The existing data handling system was not being used effectively for production surveillance because it was based on old technology and it was cumbersome to use.
The Interactive Surveillance Information System (ISIS) project was designed to provide operating and engineering staff with access to the mainframe data base without the need to learn sophisticated computer programming skills. ISIS couples an SQL mainframe data base with an interface program which runs on a PC called PCIS--PC Interface to SQL. The primary objective of the project was to develop a data handling system that would make the production surveillance data "more useable."
With ISIS a person can describe the data that he or she wants using a series of menus from PCIS. PCIS translates this description of the data into the necessary SQL code, and sends instructions to the mainframe computer. Once the data is retrieved, it can be printed or plotted or it can be transmitted back to the PC for use in other programs such as a spreadsheet or a local data base.
Multiwell Data Acquisition and Analysis for Permanent Bottomhole Pressure Gauge Installations
Authors: Schmidt H. , Stright D. H. , Forcade K. C. 
Published: December 2007

ABSTRACT
A multiwell data acquisition system has been developed for long-term, continuous monitoring of data from permanently installed downhole instruments. The data collection frequency can be controlled independently with the surface computer system for each well down to a minimum sample time of 1 second. Up to 8 wells can be monitored with the existing system; however, with modifications to the instrument controller, any number of wells could be monitored with one computer system. A database manager is built into the software. This program permits acquisition, storage and retrieval of an unlimited number of pressure data points and enables the operator to select and analyze any portion of the pressure data for any well. The system is applicable to onshore, offshore platform and subsea satellite wells. In addition, the system is compact and portable and can easily be transported to the wellsite for single-well DST and production testing.
Offshore Crude Sweetening by Gas Stripping
Authors: Allen R. F. , Smith S. J. , Walker G. J. 
Published: December 2007

Abstract
On Texaco's Tartan platform in Block 15/16 of the North Sea a crude oil treating facility has been installed to remove H2S from sour zone production and enable export to a sweet product terminal.
Selection and design of the gas stripping process is discussed together with mechanical design, control philosophy, material selection and safety considerations.
The conduct of the project is described and data presented on the performance of the unit and the efficiency of gas stripping.
The Occurrence, Prevention and Treatment of Sulphate Scale in Shell Expro
Authors: Carrell K. D. 
Published: December 2007

ABSTRACT
Shell U.K. Exploration and Production (Shell Expro) operates in the U.K. sector of the North Sea on behalf of Shell/Esso and other joint venturers.
This paper discusses operational problems experienced to date, in Shell Expro's fields, due to the formation of barium and strontium sulphate scales downhole in producing wells. Particular reference is made to the Shell/Esso Brent and Dunlin Fields.
A Continuous Operating Protection System Called Cops
Authors: Chaperon G. , Leuenberger H. 
Published: December 2007

ABSTRACT
The continuous operating protection system called COPS is a diverless solution to achieve the stabilisation and protection of subsea pipelines and cables : the system is based on the use of a continuous fabric formwork mattress which is spread on the sea bed over the pipeline or cable to be protected by a remotely controlled underwater crawler and simultaneously filled with cement grout.
The method has been successfully used in the GULLFAKS field where about 3.6 km of grout mattresses having a cross section of 2 meters by 0.2 meter have been laid.
The performances of the system are presented as well as a trade off comparison with the other stabilisation and protection methods currently used : burying, rock dumping or placement of covers.
The Transparency of Fatigue Cracks To NDT Methods Used for the Inspection of Offshore Structures
Authors: Newton K. 
Published: December 2007

ABSTRACT
This paper presents results from a study of crack transparency to NDT techniques, which has been completed for sponsors of the Harwell Offshore Inspection R and D Service. Different mechanisms which could lead to transparency to the different inspection methods are described, including crack tightness, crack morphology and the bridging of cracks by corrosion or calcareous deposits. Results are presented from experimental measurements with several NDT methods for a range of cracks grown under different conditions. Most techniques available or under development for underwater detection and sizing of cracks are included – magnetic particle inspection, AC potential drop, pulse-echo and time-of-flight diffraction ultrasonics, and eddy current methods, together with some acoustic emission measurements.
It is concluded that for tight air-grown cracks in typical offshore grade steel, large compressive stress can significantly reduce the effectiveness of most techniques. The presence of corrosion products for cracks grown in seawater generally improves performance under compressive load, especially for the electromagnetic techniques. An assessment of the factors affecting the stress distribution at welded node joints on offshore platforms indicates that cracks which are tight at the time of inspection may be uncommon, and those which do occur are likely to be under modest compression. In this case, most NDT methods should be readily applicable. The effects of deposits within more typical open cracks are also investigated.
The results are used to provide practical guidance on the choice of NDT methods for offshore inspection, in order to minimise the risk of missing or undersizing defects in situations where transparency mechanisms can be significant. Finally, the implications for the choice of samples for validation trials of underwater NDT equipment are discussed.
Simulation of CO2 Huff ‘n’ Puff Using Relative Permeability Hysteresis
Authors: Denoyelle L. C. , Lemonnier P. 
Published: December 2007

ABSTRACT
The CO2 Huff-Puff technique is becoming an attractive technique to stimulate a large variety of wells. This paper presents a new approach to the simulation of this technique, using the concept of relative permeability hysteresis.
A newly developed software was used for the study. It is made of a general purpose compositional simulator system that displays numerous specific features arranged in a modular structure. For increased efficiency, numerical models adapted to given problems, can be automatically generated from this system. In the present study, a model was generated to include among other options the kr, Pc hysteresis and to simulate the Huff–Puff process.
This study is mainly focused on low productivity reservoir for which CO2 stimulation could represent a viable alternative to being shut down.
First the case of a watered out light oil reservoir was investigated. The model was validated by successfully history –matching production data from a typical huff–puff cycle. A performance prediction was performed for additional cycles and parametric runs on amounts of injected CO2 were performed.
Then the case of a heavy oil reservoir with no water production was studied. A successful history match of three consecutive stimulation cycles was obtained. However it was found necessary to introduce a rate of gas dissolution in heavy oil, which is more representative of the physical phenomena.
A performance prediction was conducted for additional cycles; and a number of parametric runs were performed. The results show that for heavy oil, gas injectivity and oil productivity may increase with the number of cycles in an unlimited medium,higher final oil productivity is obtained with short cycles than with long ones,the influence of up to 25% hydrocarbon gas in the CO2 is limited.
Finally it appears that in both types of reservoirs, the relative permeability hysteresis is the main cause for incremental oil production. Oil viscosity plays a major role with the heavy oil only, as would normally be expected.
A New Approach to Multiphase Well Test Analysis
Authors: Al-Khalifah A-J. A. , Aziz K. , Horne R. N. 
Published: December 2007

Abstract
This paper presents a new approach to analyze multiphase well tests. In this approach, multiphase flow is modelled using the diffusivity equation with p2 as the dependent variable. This approach is applied to analyze simulated and literature multiphase tests for a range of PVT properties. Results of this approach are compared to those obtained by the pressure (Perrine's) approach, which is shown to be a special case of the new approach.
Fetkovich's empirical approach for isochronal oil-well testing has been in use since 1973 without theoretical derivation. His approach is derived here using the pseudosteady state solution of the diffusivity equation in terms of p2. The possibility of extending the isochronal testing to three phase systems is also discussed.
This paper derives the pressure-saturation relation, reported by both Muskat and Martin. Assumptions made are also investigated. Martin's total compressibility is derived without assuming negligible pressure and saturation gradients.
Finally, this paper explains the application of a new relative permeability technique, to estimate the absolute permeability of multiphase reservoirs. Two examples to verify this application are also reported.
In-Place Determination of Reservoir Relative Permeability Using Well Test Analysis
Authors: Al-Khalifah A-J. A. , Horne R. N. , Aziz K. 
Published: December 2007

Abstract
This paper describes a new method to estimate two- and three-phase relative permeabilities in-situ, using pressure transient analysis. The technique requires a short drawdown test, consisting of a number of steps of increasing flow rate. The resulting relative permeabilities reflect the properties of the whole drainage area, rather than those of a small laboratory core. The proposed technique is a major improvement over current historical performance methods. These existing methods need data over long periods, yet only cover a range of saturation up to present conditions – all future projections require extrapolation. By contrast, the new method estimates relative permeabilities at sandface saturations, which cover a range of future reservoir conditions. The well test can be repeated at a later stage of depletion to forecast still further into the future.
The proposed technique applies the solutions of multiphase diffusivity equation in terms of the pseudopressure function, m(p). These solutions have already been reported for constant rate tests in solution gas-drive reservoirs. This paper extends the pseudopressure solutions to three-phase systems. Two- and three-phase solutions are then superposed to obtain multiple-rate solutions, the basis for two- and three-phase relative permeability equations. A saturation equation developed originally by Bϕe et al. for solution gas-drive reservoirs, is also extended here to three-phase reservoirs. These pressure-saturation equations can be used to estimate sandface saturations during the test.
Using a commercial black-oil simulator, example well tests were simulated over a 40% range in gas saturation. Both two- and three-phase results show close agreement with input relative permeability curves. In cases where relative permeability is not homogeneous within the drainage area, the resulting estimates of relative permeability curves were very representative of in-situ heterogeneities.
The proposed technique offers a means to estimate two- and three-phase relative permeabilities at in-situ reservoir conditions, accounting for heterogeneities, wettability and fluid composition. It also seems to be the most appropriate way to obtain estimates for subsequent reservoir engineering analysis.
Systematic Design and Analysis of Step-Rate Tests to Determine Formation Parting Pressure
Authors: Singh P. K. , Agarwal R. G. , Krase L. D. 
Published: December 2007

ABSTRACT
Step rate testing (SRT) has been used for several years to determine the formation or fracture parting pressure (FPP). Unfortunately, little is available in the literature regarding SRT design and analysis. Further, the available guidelines are inadequate and may lead to questionable values of the FPP.
A systematic investigation of several significant factors affecting SRT design and analysis is presented. The analysis of SRT data influenced by wellbore storage and changing wellbore storage is investigated. The proper application of multirate analysis methods to SRT data is outlined. A new method is proposed for determining parting pressure from SRT data on fractured wells. Field examples are included. This work should significantly enhance our ability to successfully design and analyze the step rate tests.
Fracture Identification and Productivity Predictions in a Carbonate Reef Complex
Authors: Dennis B. , Standen E. , Georgi D. T. , Callow G. O. 
Published: December 2007

ABSTRACT
In order to optimise well completions and production in naturally fractured reservoirs and to predict the effectiveness of enhanced oil recovery schemes, it is important to locate and describe the in-situ fractures. A combination of log measurements and core data were employed to locate and orient the fractures and assess their overall contribution to reservoir performance in a Devonian reef complex. These techniques include the imaging of the wellbore with the Formation MicroScanner Log (FMS)* and the Borehole Televiewer (BHTV). The image data were compared to detailed core analysis, where available, and were used to determine the length, orientation and probability of fractures as a function of porosity. The Array-Sonic* tool was also run to help identify fractured zones using full waveform data and to quantify producibility from Stoneley wave data in comparison to flowmeter production logs.
From the comparison of the images with core, the utility of the FMS and BHTV Logs were established in identifying fractures and fracture sets as well as detenriining the orientation and vertical extent of the fractures. In addition, the response of FMS images to different porosity types was confirmed by core data. Comparison of the Array-Sonic data and the flowmeter production log data established the usefulness of the Stoneley wave attenuation as a means of identifying permeable zones.
The study results permit better definition of tool response to porosity types and fractures, and reveals the influence of fractures on the overall production of the reef complex. These results have implications on the initial and secondary production techniques of this and other carbonate reservoirs.
Exact Solution of Double-Porosity, Double-Permeability Systems Including Wellbore Storage and Skin Effect
Authors: Liu X. , Chen Z. , Jiang L. 
Published: December 2007

Abstract
The mathematical model describing flow of slightly compressible fluid through a double-porosity and double-permeability medium is solved rigorously with consideration of wellbore storage and skin effect. The exact solutions obtained for a well producing at a constant rate from a radial drainage area with no-flow or constant-pressure outer boundary condition are expressed in terms of ordinary Bessel functions. The numerical computation of these solutions is made and the behavior of the systems is studied as a function of various reservoir parameters. The limitations of the Warren and Root model are also examined.