bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Kurunda Field Tirrawarra Reservoir: A Case Study of Retrograde Gas-Condensate Production Behavior
Authors: Hueni G. B. , Hillyer M. G. 
Published: December 2007

Abstract
The Kurunda Field, Tirrawarra sandstone is a low permeability, lean gas condensate reservoir located in the Cooper Basin of South Australia. Prior to production consideration was given to the need for gas cycling to maximize liquid recovery. Early long-term production tests, however, showed a much larger drop in liquid-gas-ratios than expected. A study was undertaken to determine the cause of this drop and the implications with respect to future operational policy.
A comparison of field observed performance and laboratory data indicated a reservoir fluid composition intermediate between that measured on two laboratory samples. Field observed performance together with results from a simplified model of retrograde gas condensate reservoir behavior further indicated that the observed liquid-gas-ratio correlated more closely to the bottomhole flowing pressure rather than the average reservoir pressure. This liquid-gas-ratio behavior was found to result from the near wellbore region of the reservoir acting as a separator and preventing the recovery of liquids originally entrained in the gas. This separation effect which continues for the life of the reservoir adversely effects liquid recovery for both primary and pressure maintenance operations, and prevents the economical application of the latter activity.
Gravel Packing in High-Rate Oil Completions
Authors: Shucart J. K. , Rustandjaja A. F. 
Published: December 2007

Abstract
Forty nine high rate oil wells were completed with gravel packs in Maxus' Intan/Widuri fields in a nine month period. Lower than expected productivity on the initial completions resulted in an extensive investigative test program conducted primarily at the field level. The test program, the procedures used and the results of these tests are reviewed. The investigations include fluid and gel compatibility with the formation, determination of the critical gravel pack slurry parameters, pressure losses across different screen types, and the outcome of various gravel placement techniques.
The primary conclusions are as follows. Slurry gel viscosity was the most critical parameter in the amount of gravel placement. Perforation washing in conjunction with underbalanced tubing conveyed perforating (TCP) gave significantly better gravel placement and productivity than only underbalanced TCP. The use of a short cleanup test following completion is beneficial in early identification of a production impairment.
Cossack Development – First Oil for Woodside
Authors: Seymour E. V. 
Published: December 2007

Abstract
The Cossack oilfield will be Woodside's first "oil" development The Cossack #1 discovery well was drilled in January 1990, and encountered a gross oil column of 54 m. Recoverable reserves are estimated to be 60 million bbl "expectation" and 30 million bbl "proven". Screening studies of a number of development alternatives were quickly completed In April 1990. These studies were followed by more detailed feasibility studies, concluded in September 1990, which confirmed that the field was ideal for a standalone development A project team was formed and project definition studies completed in January 1991, ultimately leading to full budget approval in July 1991. First oil is scheduled for June 1993, three and a half years from the date of the discovery well. It is planned to recover the oil by means of up to six subsea wells, drilled in a cluster and tied back to a Floating Production, Storage and Offloading (FPSO) vessel. This will be a converted 155,000 dwt tanker which will be moored via a disconnectable system, thus being able to steam out of the path of tropical cyclones which regularly pass through the area.
Evaluation of Steam-Injection Designs for the Duri Steamflood Project
Authors: Fuaadi I. M. , Pearce J. C. , Gael B. T. 
Published: December 2007

Abstract
The Duri Steamflood (DSF) Project is the largest thermal enhanced oil recovery (EOR) project in the world, surpassing in production both Kern River and Belridge in the San Joaquin Valley of California. The field is located in Riau Province on the island of Sumatra, in Indonesia. Duri is the second largest field in the country, producing nearly 200,000 BOPD of steamflood production. The field is being operated and developed by P.T. Caltex Pacific Indonesia (CPI), a production sharing contractor to Pertamina.
The DSF Project will develop about 15,000 acres of reservoir utilizing over 4000 producing wells. At present, only about 1/3 of the field is under active steamflood. The DSF Project is divided into twelve development units called Areas. New Areas are about 1400 acres in size and are developed, that is drilled and put on injection, every 1 3/4 to two years.
The steamflood development involves the use of symmetric patterns of varying size and configuration. Inverted seven spots, approximately 11 5/8 acres in size, have been the *References and figures at end of paper principal pattern configuration for Area development thus far, including the Area currently being drilled [1]*. For future Areas, inverted five and nine spots, approximately 15 1/2 acres in size, are planned. This change will be implemented as a result of detailed reservoir simulation studies conducted in CPI [2].
Pattern producer completions are either cased hole gravel packs (CHGP) or, more commonly, open hole gravel packs (OHGP). Most OHGP wells have 10 3/4" casing set at the top of the drive zone, hole opened to 14", and packed with 20-40 US mesh gravel outside of 6 5/8" screen liners. Up to four distinct sand intervals and 250 ft of pay are simultaneously completed and flooded in a single pattern.
The main challenges in downhole design and completion of DSF's steam injection wells have arisen from the relatively large pattern sizes and the need to distribute high rates of steam to multiple intervals of varying permeability. Several different, multi-point, downhole injection systems have been used in Duri.
The design, field testing, and evaluation of these various systems are here presented and discussed.
Improved Productivity Through Automation of Data Gathering Activities on Offshore Platforms
Authors: Wong S. W. , Muhamad Jasni 
Published: December 2007

ABSTRACT
This paper describes a project implemented by Esso Production Malaysia Incorporated (EPMI) to improve the efficiency and effectiveness of the data gathering and reporting activities on offshore platforms.
The Platform Data Capture project (PDCAP) will automate data gathering, transfer, processing and reporting of production and operation data from offshore platforms. The implementation of the PDCAP project will allow EPMI to capture production and operation data on offshore platforms using existing computing technology in combination with hand-held data entry terminals, personal computers and data acquisition mini-computers.
The PDCAP project demonstrates the use of computing technology to reduce time spent by offshore staff on routine manual tasks of data gathering and reporting. This results in increased time for the staff to perform the more important facility surveillance and trouble-shooting work which then translates to safer and more effective platform operations.
Waterflood Performance Of A Shallow Channel Sandstone Reservoir Burkett Pool, Coleman County, Texas
Authors: Patton E.N. 
Published: December 2007

American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc.
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
A summary of performance and development through primary and secondary oil recovery phases of a shallow channel sandstone phases of a shallow channel sandstone reservoir of Permian age is presented. Discussion will concentrate on Amerada Petroleum Corporation's leases in the Petroleum Corporation's leases in the Burkett pool, Coleman County, Texas.
Very few early records are available; however, the discovery well was apparently drilled in 1924. Development was rapid on about 3 to 4 acre spacing. Practically all of the geologic information available is from drillers' logs. The reservoir is found at a depth of about 390 ft.
Water injection began in 1947 when produced water was injected into the pay produced water was injected into the pay section of two wells. In 1958 full scale waterflood operations were initiated. Primary recovery amounted to 22.4 per cent Primary recovery amounted to 22.4 per cent of the 11 million bbl oil originally in place while secondary recovery to June 1, 1968, was 12.3 per cent. A remaining 4.1 per cent is expected to be recovered under current operations even though the field has been producing at water cuts above 97 per cent producing at water cuts above 97 per cent for two years. Out of 209 wells drilled, 54 are currently producing a total of approximately 325 BOPD and 12,500 BWPD. Twenty-five wells are being used for injection amounting to about 14,000 BWPD.
It will be shown that a lack of data, haphazard spacing, and difficult well completions can be overcome to initiate a successful waterflood.

Introduction
The Burkett pool is located in northeast Coleman County, Texas, approximately 6 miles southwest of Cross Plains, Texas, and 45 miles southeast of Abilene, Texas, and is officially listed by the Railroad Commission of Texas as the Coleman County Regular field. This paper will present data solely from Amerada Petroleum Corporation's J. W. Harris, J. W. Harris "A", and W. T. Burns leases, which comprise about 80 per cent of the Burkett pool.
The purpose of this paper is to review the performance and development through primary and secondary oil recovery phases primary and secondary oil recovery phases of a shallow channel sandstone reservoir. Also data will be presented to support the fact that in an old pool, where unfavorable well conditions exist and much data is missing, waterflood operations can be successfully conducted.
Technical Considerations In The Design For Project Bronco
Authors: Lombard David B. , Bray Bruce G. , Sohns Harold W. 
Published: December 2007

Abstract
Project Bronco has been proposed as an experiment to determine whether nuclear explosions can be used in the recovery of oil from deep oil shale deposits. The experimental objectives of Bronco are: to evaluate the overall feasibility of nuclear breaking followed by in situ retorting; to investigate the gross physical effects of a nuclear explosion in oil shale; and to assess the role of radioactivities in the production of oil by in situ retorting.
A proposed experimental site in the Piceance Creek Basin of Northwestern Colorado is described. Plans for site preparation and for emplacement and detonation of the explosive preparation and for emplacement and detonation of the explosive are discussed, as are studies to be made of the underground heat and radioactivity, of the geometry of the nuclear chimney, and of the fracturing of the oil shale. Preliminary plans for oil recovery from the nuclear chimney are reviewed.
Before this application of underground nuclear explosions can become commercially feasible, a variety of technical problems must be examined. Some of these are related to nuclear explosion effects, others to the recovery of oil from the broken rock. Consideration of these factors is followed by a discussion of some long-range technical aspects for the development of a commercial technology.
The Effect Of Asphaltic Materials On The Viscosity And Non-Newtonian Behavior Of Crude Oil
Authors: Witherspoon P.A. , Datta P. , Nagy G. 
Published: December 2007

Publication Rights Reserved
This paper is to be presented at the 32nd Annual California Regional Meeting of the Society of Petroleum Engineers of the American Institute of Mining, Metallurgical and Petroleum Engineers in Bakersfield, November 2–3, 1961, and is considered the property of the Society of Petroleum Engineers Permission to publish is hereby restricted to an abstract of not more than 300 words, with no illustrations, unless the paper is specifically released to the press by the Editor of the Journal of Petroleum Technology or the Executive Secretary. Such an abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in Journal of Petroleum Technology is granted on request, provided proper credit is given that publication and original presentation of the paper.
Discussion of this paper is invited. Three copies of any discussion should be sent to the Society of Petroleum Engineers office, and no Discussion should exceed ten percent of the manuscript which it discusses. Such discussions may be presented at the above meeting and be considered for publication in Journal of Petroleum Technology with the paper.

Abstract
Asphaltic materials play a very important role in controlling the viscous behavior of crude oil. This has been revealed by a series of rheological studies on five California crude oils ranging in gravity from 150 to 250 API. The asphaltene contents of these oils range from 4% to 21% by weight. Detailed measurements of viscosity have been carried out at atmospheric pressure at temperatures ranging from 250 to 60 deg. C (77 deg. to 140 deg. F) using a Ferranti cone-plate viscometer. Oil viscosities have been studied at shear rates to 2000 sec.
Although crude oils are generally considered to be Newtonian fluids, the asphaltic oils of this investigation exhibit pronounced pseudoplastic, non-Newtonian behavior.
Simulation of a Highly Deviated Well in a Naturally Fractured Reservoir, Lake Maracaibo, Venezuela
Authors: Sanchez N. , Marín A. , Rattia A. 
Published: December 2007

Abstract
A dual porosity simulator was used to evaluate the feasibility of drilling high angle slant wells in the naturally fractured cretaceous reservoir VLA-515, which is located in a geologically complex zone constituted by interconnected fractures where the risk and drilling costs are considerably high.
Simulations were conducted to reproduce the existing reservoir conditions, and predictions were made to compare the performance of stimulated vertical wells with horizontal, and slant wells.
The production potential predicted for the slant well was twice higher than the achieved by the vertical well, in addition of increasing the oil recovery by 3 %.
Simulation results showed that the slant well will recover aproximately 9 MMSTBO during the first 5 years, while the vertical well requires 11 years to obtain the same cumulative production.
Finally, under the conditions of the VLA-515 cretaceous reservoir a 55 degrees slant well will achieve higher recovery than an horizontal and stimulated vertical wells, due to higher amount of contacted fractures as consecuence of its penetration angle into the reservoir.
Screening and Economic Criteria for Horizontal Well Technology
Authors: Crouse P. 
Published: December 2007

Abstract
Horizontal drilling technology has become an economic reality, and the result has been a dramatic upsurge in the number of horizontal wells drilled. As the industry's experience of drilling, completing, and producing horizontal wells increases, so does the realization that horizontal technology is not always a solution to the problem of more cost-effective production. When evaluating the potential benefits of completing wells horizontally in a specific reservoir, the performance of the reservoir as well as the economics of drilling and completing the wells must be examined.
No matter why a horizontal well is drilled, the decision to drill must come from results that analyze all reservoir data available. Technical successes and economic failures already associated with horizontal wells over the last three years have brought home this point.
Evaluation of Cuttings Transport in Horizontal and Near Horizontal Wells - A Dimensionless Approach
Authors: Martins A. L. , Santana C. Costapinto 
Published: December 2007

Abstract
A mechanistic model is presented to describe the stratified flow of solid-non newtonian fluid mixtures in horizontal and near horizontal eccentric annulli. The model consists of a two layer configuration, the top layer being a heterogeneous suspension and the bottom one a compacted bed of solids. It is based on conservation laws of mass and linear momentum as well as on constitutive relations which describe the interactions between the phases and between each phase and the walls. The model is applied to the several flow patterns that characterize the solid-liquid horizontal flows.
The use of the Lockhart-Martinelli dimensionless parameter, modified for solid-liquid flows, permits a concise evaluation of the cuttings transport phenomena. Dependent variables, such as solids volumetric concentration, bed height and annular friction losses, can be predicted by estimating the modified Lockhart-Martinelli parameter and the flow regime of the upper layer.
Directional Drilling Expert System
Authors: Martinez E. 
Published: December 2007

Abstract
Minimizing the cost of drilling a directional well is a major concern for the drilling engineer. This computerized system was developed in order to provide the drilling engineer with an advisory tool which recommends changes in the Bottom Hole Assemblies (BHA). This results in better accuracy and faster decision making; hence, considerable savings in time and money.
The system involves five integrated modules:
– A knowledge base where all the expertise concerning the subject is stored. – A database with information from the BHAs used in drilling of previous directional wells and their statistical behavior. – A database with information from the theoretical behavior of BHAs commonly used in directional drilling. – A database with information from directional surveys performed over the path of the bore hole. – Computerized applications developed to calculate and plot the path of the bore hole.
This system was developed using an expert systems technology, including a knowledge base and a inference engine. The computerized applications for plotting and calculating the course were developed in a conventional way using BASIC and PASCAL: Databases were all developed in a relational model.
Drilling Hard and Abrasive Formations with PDC Bits
Authors: Vargas J. E. 
Published: December 2007

Abstract
Due to the success obtained by PDC bits drilling unconsolidated formations of Miocene age several designs have been tested in an attempt to extend the PDC bit application range to the harder an more abrasive formations of Ceuta field, in western Venezuela.
Satisfactory results were obtained drilling the coper section of Mi soa formation of Eocene age when compared to the previous runs using conventional tri cone bits.
These promising results, motivated the search for a better bit design to improve drilling in hard and very abrasive formations deeper in the well.
The efforts of Research Departments of main PDC manufacturers are focused toward designing a more resistant cutter to temperature and more appropriate bit profile to reduce bit whirl•.
Determination of Design Temperature for Cement Slurries
Authors: Zacarias D. 
Published: December 2007

Abstract
One of the most important parameters to obtain for the appropiate cement slurry is the bottom-hole temperature which will determine the type and amount of additives needed in the slurry to achieve the required properties. At present, a new technique has been developed to determine the bottom hole circulating temperature based on data gathered with electronical tools.
Field application has produced very reliable data that one can use to calculate the required BHCT that a cement slurry will encounter.
With the application of this technology the slurry designs have been improved, and the costs have been reduced to about 27% for the production liners and 38% for the production casings.
100% Oil Liquid Phase Drilling Fluids for Deep Wells
Authors: Larreal E. , Bandeira A. , Pérez M. A. 
Published: December 2007

Abstract
The Colon Formation Shale (Southern area of Lake Maracaibo) and The Carapita Formation Shales (Northern area of Monagas) have been frequently drilled with invert emulsion oil base mud (IEOM) for shale inhibition purposes. However, this fluid is not the most desirable for use in drilling the Cretaceous and Oligocene productive Formation since the IEOM requires high concentrations of surfactant emulsifiers which have proven to be damaging to the pay zone.
The problem described above led to the search for a mud system formulated with 100% Oil continuos phase. It was required that this system be stable to high temperatures; have no interaction with the shale cores taken from the Colon and Carapita formations; and be formulated without strong emulsifiers.
The first part of the research was carried out in the laboratory where many formulations were tested to very high temperatures and under contaminated conditions. Return permeability tests were also run to ensure that the system would minimize formation damage. The 100% Oil mud formulation from the laboratory was then used in the Southern area of Lake Maracaibo on the well SLB-4 and in the Northern area of Monagas on the well BOQ-8. Excellent results were achieved on the trial wells in both areas and improved production rates obtained on well SLB-4 compared to other wells in the field which were drilled with standard IEOM.
The Determination of Polarity for Crude Oil Demulsification
Authors: Brüning I. M. De Andrade 
Published: December 2007

ABSTRACT
A demulsifier to be effective in breaking a water-in-oil emulsion has to possess higher polarity than that of the crude oil natural surfactants. In spite of the polarity of those natural surfactants has never been measured, this general rule guided the use of chemicals in oil treatment along the years of the petroleum industry. Previous work developed a method to measure oil polarity, which proved that crude oils differ widely in their polarities. Present work extends this method to evaluate the polarity of several commercially available chemicals for crude oil demulsification. Because asphaltenes are considered to play a decisive role in emulsion stability, their polarity was also determined. The results provided an overall comprehension about the polarities involved in crude oil demulsification.
Physical Aspects of Formation Damage in Linear Flooding Experiments
Authors: Eleri O. O. , Ursin J-R. 
Published: December 2007

Abstract
The infiltration of fine particles into the reservoir and the resulting production decline has long been a problem to the petroleum industry. It is also generally accepted that formation damage due to particle plugging is not thoroughly understood. In contributing to the solution of this problem, an experimental study of more than 17 core plugs involving 25 linear runs has been conducted. The purpose was to study the different physical and mechanical aspects of the processes leading to formation damage caused by movement and entrapment of suspended particles (when chemical and other forces are minimized).
Permeability is a key parameter among several others that control reservoir performance. The experiments are based on the results of permeability decline in linear core tests.
Two methods of flood tests; constant flow rate and constant pressure drop, were used on Berea sandstone. Plastic particles were injected with ultra pure water as the transport medium. Essential filtercake properties required for the decline rate calculations were obtained.
Finally, particle characterization using the Coulter counter was analysed. The results combined with that of the filtercake properties were used to determine the mechanisms and extent of plugging.