bluuebunny/crossref_metadata_2025_split huggingface dataset:
Zonal Control With Single Selective Completions Udang Field — Natuna Sea — Indonesia
Authors: Rodriguez Fernando H. 
Published: December 2007

Abstract
Discovery and delineation wells which proved the Udang Field did not yield sufficient data to indicate the complexity of the reservoir. Development drilling showed the Udang pay section to be a series of interbedded shales and sands having individuals gas caps and water/oil contacts. The initial plan, to complete the wells by perforating a 40-foot section and installing a screen with slurry pack, was quickly changed in favour of multi-zone single selective completions.
This paper describes the various types of completions and equipment used, and the success achieved by utilizing single selective completions to control excessive gas and water production.
The field commenced production in January 1979. Since then to the present, about 100 trips nave been made with wireline tools to open or close sliding sleeves with only one failure. In 3 wells the same sliding sleeve was successfully actuated six times. This has been achieved even though some wells have 65 degree inclinations and most all wells produce measurable amounts of sand. It is concluded that these type completions have substantially increased present and projected oil recovery from the Udang Field.
The occurrence, Causes and Detection of Abnormal Pressure in the Malay Basin
Authors: Singh Indarjit , Ford C. H. 
Published: December 2007

Abstract
Abnormal pressure strata are believed to exist throughout the Malay Basin with the exception of the southwest and northeast margins. The onset of abnormal pressure is abrupt in the northeastern portion of the basin but is generally more gradual in the southeastern area.
The abnormal pressure is a complex origin and is attributed to a combination of rapid burial of certain stratigraphic units, uplift of initially normally pressure strata, faulting and hydrocarbon column effects.
Predrill abnormal pressure predictive techniques used by EPMI in the Malay Basin are interpretation of seismic interval velocities and electric log correlation. With accurate seismic velocity information, an interval transit time profile, called a Pennebaker plot has aided in predicting top of abnormal pressure in 80% of the wells drilled to date. Log correlation is most applicable within the confines of a particular structure.
Detection of abnormal pressure in the Malay Basin while drilling is difficult at standard pressure indicators while drilling and use of industry generated overlays to derive quantitative estimations of pore pressure from drilling exponent plots do not provide satisfactory results. As a result, EPMI developed a "Malay Basin" overlay which provides more accurate quantitative estimation of pore pressure from drilling exponents. In addition, EPMI employs a technique for monitoring gas feed-in, called an extended connection, or 10-10-10 to detect geopressure while drilled.
Development of Pabelokan Island
Authors: Powell D R 
Published: December 2007

Abstract
PERTAMINA-IIAPCO has an expanding complex of offshore production platforms in the Southeast Sumatra Contract Area of the Java Sea. One of the requirements for this complex is a treatment facility for water to be used in secondary recovery operations. Because of the water quality required, the water treatment system is substantially larger than that normally used offshore. Instead of constructing one or more platforms for the treatment system, a small coral Island named Pabelokan Island has been utilized for this purpose. Although the water treatment system is the primary reason for the base, other facilities were co-located to centralize: electrical power generation, living quarters and recreation facilities, and facilities for storage and maintenance of offshore equipment. Future plans for the Island include a gal-liquids recovery system.
This paper describes the Island facilities, and provides a case study in responsible planning and construction techniques in the development of a coral Island for use as an offshore base. The experience gained should be useful in the planning of other coral Islands for similar purpose.
Financial Evaluation of An Offshore Drilling Rig Venture
Authors: Slaughter Lou S. 
Published: December 2007

Abstract
The paper is a financial evaluation of an offshore drilling rig venture. It pertains to other ventures world wide involving substantial investments in offshore marine equipment. The scope of the paper ranges from a discussion of the drilling industry to the financial proformas covering the operation of the equipment.
The points that the presentation covers are as follows: The structure, economics, marketing and financing of the drilling industry.The strategic matching of the opportunity with the operating environment, resources and management disposition of the company.A financial analysis of the venture, including: "Back of the envelope analysis."Construction period projection.Proformas as at commencement of operations.Operating projection.Net present value analysis.
Additionally the paper draws attention to issues that are important to the above evaluation.
The paper should enlighten and be well received by those participants to the conference who are mainly orientated towards the technical side and not the financial aspects associated with marine ventures.
An Implementation of a Fully Implicit Reservoir Simulator on an ICL Distributed Array Processor
Authors: Scott A. J. , Sutton B. R. , Dunn J. , Minto P. W. , Thomas C. L. , Habib S. , Oakley C. A. , Krzeczkowski A. J. 
Published: December 2007

ABSTRACT
An oil/water, 3-D fully implicit Reservoir Simulator has been implemented on the ICL Distributed Array Processor (DAP), by a joint BNOC/ICL project team. The DAP is a single instruction, multiple data stream machine with 4096 processors in parallel.
The major computational areas of code have been implemented on the DAP, leaving I/O and well calculations as serial code on the host 2976 machine. Matrix assembly is inherently parallel and can be implemented easily and efficiently on the DAP with compact code. Table look-up, though not obviously parallel, has been coded using a very efficient parallel algorithm.
The Linear Solver, of Line Gauss-Seidel type, has been chosen for its efficiency on the DAP, with odd and even reduction used for solution of the resulting tri-diagonal equations. Further research will be undertaken to increase the robustness of this solver.
The initial implementation has a 1-1 mapping of active grid blocks to processors, thus allowing up to 4096 active grid blocks. It is planned to extend to much larger models, and to 3 phase.
Modelling the Piper Field Using Layer Cross Flow at Faults
Authors: Dunlop K. N. B. , De Boer E. T. , Waldren D. 
Published: December 2007

ABSTRACT
A special finite difference simulator was coded and used to model the Piper Field, which is a large faulted reservoir consisting of layers of contrasting but high permeability. The formulation allows any number of connections between grid blocks providing the flexibility to include fault throw as a variable during three-dimensional history matching. Because correspondence between geological and model layers is preserved, model cost and complexity are reduced.
Acrylamide/Acrylic Acid Copolymers for Cement Fluid Loss Control
Authors: McKenzie Lee Frederick , McElfresh Paul Michael 
Published: December 2007

ABSTRACT
Acrylamide/acrylic acid copolymers are effective fluid loss control additives in a wide range of oil well cements. Unlike HEC based fluid loss additives, these copolymers can be used with calcium chloride accelerator without significantly influencing fluid loss control. Another advantage of the copolymers is that the amount of fluid loss for a given concentration of polymer remains relatively constant over a wide range of temperatures. The use of acrylamide/acrylic acid copolymers has generally been restricted to wells below 60°C BHCT. Above that temperature chemical changes in the copolymer often lead to retardation of the cement.
This paper presents data related to the use of acrylamide/acrylic acid copolymers as fluid loss control agents in oil well cementing. A comparison of these polymers with HEC based fluid loss control additives is made. In addition, data related to the cause of acrylamide/acrylic acid copolymer retarding effects is presented.
Easy Brine Flash Estimates
Authors: Kouzel Bernard 
Published: December 2007

ABSTRACT
The author shows that the enthalpy of sodium chloride solution expressed on a unit weight of water basis is essentially equal to the enthalpy of pure water at the same temperature.
The use of this concept is illustrated for rapid and accurate adiabatic flash calculations involving geothermal brines.
A steam table is used instead of a brine enthalpy table and the simplifying assumption of pure water as the geothermal fluid is not necessary.
Comparison of Conventional and Type Curve Analysis of Pressure Falloff Tests for a West Texas Carbonate Reservoir
Authors: Crawford Duane A. , Waller Herschel N. , Sanders L. J. 
Published: December 2007

ABSTRACT
Pressure falloff data collected in moderately fractured water injectors in a West Texas carbonate reservoir are analyzed using both conventional and type curve techniques, and results of these analyses are compared. The theory and application of the two methods are also discussed. The technique of Hadinoto and Raghavan is used to calculate corrected water permeability capacities and fracture lengths by conventional techniques and to determine the same parameters by type curve analysis. Included are example calculations showing the agreement between water permeability capacity and fracture length using the two approaches and between these parameters calculated for several pressure falloff tests on the same well.
An Improved Method for the Rapid Detection of Microbiological Contamination in Stimulation Fluids
Authors: Penny Glenn S. 
Published: December 2007

ABSTRACT
This study introduces a method that makes possible the direct monitoring of stimulation fluids for microbial contamination. The procedure is based on the assay of adenosine triphosphate (ATP) with luciferin-luciferase. The accuracy of this method is compared to conventional plate counting and nutrient vial dilution techniques. The effects of stimulation fluid additives such as KCl, biocides, buffers, and gelling agents are assessed, and a procedure for the differentiation of bacterial vs. nonbacterial ATP is examined. Data showing the utility of the assay in monitoring biocide effectiveness and predicting batch mixed gel degradation are presented.
Performance Evaluation of Acid Treatments in Seawater Injectors With Reference to Acid Volume Impact
Authors: Beheiri Faisal I. , Nasr-El-Din Hisham A. 
Published: December 2007

Abstract
Acid matrix treatments in carbonate reservoirs create a network of passages in the near-wellbore zone. The acid volume is a key variable that determines the effectiveness of acid treatment. For matrix treatments, the acid volume ranges from 20 to 100 gal/ft. Acid concentration ranges from 15 to 20 wt%. Selection of acid volume and concentration varies based on engineering experience and judgment.
This paper presents an analytical model for calculating time-lapsed injectivity index (II) in order to verify the impact of acid volume with all other contributing variables being fixed. The model integrated matrix acid treatments; injection profile surveys, injection data, completion configurations, and reservoir parameters. The model has been applied on six stimulation treatments where all contributing variables varied, except the acid volume. A normalized performance indicator was characterized based on the II's initial improvement, decline rate, and cumulative improvement.
The calculated IIs by the model successfully matched the measured IIs by the fall-off tests. The model evaluated the treatments contributing variables and established clear correlations between acid volume and the post stimulation performance.
A Study of Getty Oil Co.'s Successful In-Situ Combustion Project in the Bellevue Field
Authors: Long Ralph E. , Nuar Mark F. 
Published: December 2007

Abstract
The in situ combustion project operated by Getty Oil Company in the Bellevue Field, Bossier Parish, Louisiana, has expanded from a single pilot pattern in 1963 to a full-scale operation with more than one hundred patterns in 1981.
Originally discovered in 1921, the field produced for about ten years under primary production methods. The field remained relatively dormant until Getty Oil Company conducted a successful in situ combustion pilot which commenced in 1963. The project is now producing about 2900 barrels daily of 19.5° API gravity crude from 350 producing wells.
Pattern sizes and configurations have varied during the eighteen year project. Wet and dry combustion methods have been used in the field and a combination of the two methods is used today depending on the stage of burn the pattern is experiencing. Several water-air injection ratios have been tried with varying degrees of success.
In this paper, Getty's Bellevue project is traced from its inception to the present. Response to various methods used in the field as well as operational problems are discussed. Ultimate production forecasts are also presented for the field.
Knowledge Management for Shared Earth Modelling
Authors: Mastella Laura , Perrin Michel , Abel Mara , Rainaud Jean-François , Touar Walid 
Published: December 2007

Abstract
Shared Earth Modelling (SEM) describes the process of integrating static (geological structures) and dynamic data (hydrocarbon production) issued from several disciplines to construct a model of a subsurface resource. We claim, however, that SEM should allow sharing and integrating not only data but also the knowledge related to data interpretation. As a consequence, actors from different disciplines, who have different technical skills, should be able to provide a "Shared Earth Model" with specific technical knowledge concerning how to evolve a hydrocarbon prospect at the various stages of its life cycle.
The integration of various levels of scientific and technical knowledge into the modelling process requires an overall view of the knowledge and data workflow. In order to enhance a knowledge management approach, we first examine which types of information (data, interpretation, abstract model, symbolic or spatial representations) should be considered at each step of the reservoir modelling chain. Moreover, in order to allow each expert to bring his/her own contribution in an explicit way, we propose the use of a formal vocabulary related to the different disciplines and define it through ontologies. It is thus possible to picture how the various types of knowledge should interact for producing consistent "Shared Earth Models".
In order to illustrate the above approach, the paper presents a prototype of "Geological Knowledge Editor" (GKE). This module allows representing the knowledge acquired at the beginning of the SEM process and providing services to enhance this knowledge and checking its consistency, guaranteeing thus the quality of service (QoS) attached to the reservoir modelling process. By means of the GKE, the geologist can display geological representations such as fault networks or stratigraphic columns. He/she can also edit the chronological interpretation attached to the model and use it for building structural models in an automatic way.
Analyzing an Oilfield Gas Handling System
Authors: Earhart James W. , Mathur Anil , Haire William M. 
Published: December 2007

ABSTRACT
Reconciling "as designed," "as built," and "as operated" for a complex field gas handling system is crucial to planning system modifications. Field measurements of one such system show extreme scatter, making a consistent prediction of system capacity extremely difficult. Statistical methods make it possible to develop a model of system behavior which is valid over a wide range of operating conditions.
Steam Injection Theories — A Unified Approach
Authors: Farouq Ali S. M. 
Published: December 2007

ABSTRACT
Formation heating and oil displacement by steam injection is a multi-faceted process, which can take several forms. A number of theories have been proposed over the years to explain the mechanics of steam advance in an oil-bearing formation. These range from steam frontal advance to frontal-vertical advance to vertical advance. The premises of these theories vary considerably, but they often give the same ultimate recovery – as shown in this paper. The reasons for this apparent insensitivity are examined. The situation becomes more complicated when bottom water or formation parting is involved, inducing preferential movement of steam in still other directions than those mentioned above.
The paper provides a comparative examination of the above theories, in the light of field experience, numerical simulation and physical model results. The objective is to develop criteria for judging the applicability of one or the other -or, even more than one - theory. A simplified steamflood calculation method is also suggested.
The paper also discusses the principal mechanism of oil displacement by steam, both for light and viscous oils. It seems that the temperature dependence of relative permeabilities is an important factor in the gas drive effect of steam, and should be included to represent the oil recovery process properly.
Application of the above theories to cyclic steam stimulation is problematic, partly because resaturation of the depleted zone may occur.
The Use of Foam in Stimulating Fractured California Reservoirs
Authors: Norton Mike G. , Hoffman Steve J. 
Published: December 2007

ABSTRACT
The majority of oil reservoirs in the Ventura Basin consist of massive sand sections inter-bedded with shales and clays resulting in low to extremely low matrix permeabilities. The geologic tectonic activity surrounding this basin has produced a number of fractured sandstone reservoirs. A well completion in these reservoirs must include hydraulic fracturing to obtain a commercial well.
The Sespe Field located in central Ventura County (T4N,R19-20W;T5N,R19-20W) and the Holser Canyon Field located in eastern Ventura County (T4N,R20W) are characterized by tight, thick (50-300 ft) sands with moderate to extensive natural fracture systems. Hydraulic fracturing stimulation treatments have been performed on wells in these fields as an initial completion practice. A great number and variety of fracturing treatments have been performed, with lease oil fracs proving to be the most successful. Other fluids used have ranged from emulsified lease crudes to nitrified crosslinked gels.
Foams have characteristically exhibited superior leak-off control and rapid clean-up, as well as an ability to carry proppant effectively. These factors are necessary to achieve a mechanically efficient fracture treatment. The use of oil based foam fracturing fluids was initially accomplished in the Rocky Mountains region to overcome fluid compatibility problems. These same problems exist in California sands and have been overcome to a large extent by the use of the oil-based systems. The use of foams as fracturing fluids has resulted in a number of successful stimulation treatments, with initial production rates as high as 80 BOPD- In the author's opinion, the foam based fracturing technique is an economical and technically viable method of stimulating the aforementioned fractured reservoirs.
This paper will describe the geology, completion practices, and fracturing techniques used to stimulate the Sespe and Holser Canyon Fields.
Steam Surfactant Systems at Reservoir Conditions
Authors: Al-Khafaji Ali Habib , Wang Pin-Ton Fred , Castanier Louis M. , Brigham William E. 
Published: December 2007

ABSTRACT
Mobility control is one of the main problems in steam flooding. Channeling of steam through highly permeable zones and gravity override lead to early steam breakthrough at the production wells. Accordingly, volumetric sweep efficiency and oil recovery are reduced. Foam has been proposed as a permeability blocking agent in steam flooding to improve oil recovery.
This paper describes two experiments. One is on static properties such as thermal stability, adsorption and partitioning; the other is on dynamic displacement by steam in the presence of surfactants. The aim of this study is to investigate some commercially available and experimental foaming chemicals (surfactants) for their longevity under simulated steam injection conditions, namely at 400°F (205°C) and 300-500 psia (20-34 bars). The steam injection experiments have been conducted in a linear flow model to study flow, heat transfer and mobility.
A Detailed Geologic Study of Three Fractured Devonian Shale Gas Fields in the Appalachian Basin
Authors: Shumaker Robert C. 
Published: December 2007

ABSTRACT
Analysis of three shale gas fields illustrates the importance of basement structure in developing fracture permeability within the thick Devonian shales of the Appalachian basin. A porous fracture facies within the organic rich lower Huron shale member of the Ohio Shale relates to a regional stress field created by differential shortening of overlying sedimentary section across the lower Huron detachment zone during the Alleghanian deformation. Greater permeability (commercial) occurs near the outer margin of tectonic shortening. Linear trends of wells with abnormally high final open flows relate to linear trends of highly fractured shale. These trends were probably caused by unique stress fields created along flexures in the shale above basement fault zones.
Synthesis of Organic Geochemical Data From the Eastern Gas Shales
Authors: Zielinski Ronald E. , McIver Richard D. 
Published: December 2007

ABSTRACT
Over 2400 core and cuttings samples of Upper Devonian shales from wells in the Appalachian, Illinois, and Michigan Basins have been characterized by organic geochemical methods to provide a basis for accelerating the exploitation of this unconventional, gas-rich resource. This work, sponsored by the United State's Department of Energy's Morgantown Energy Technology Center, was part of a program initiated to provide industry with criteria for locating the best areas for future drilling and for the development of stimulation methods that will make recovery of the resource economically attractive.
The geochemical assessment shows that the shale, in much of the Appalachian, Illinois, and Michican Basins is source rock that is capable of generating enormous quantities of gas. In some areas the shales are also capable of generating large quantities of oil as well. The limiting factors preventing these sources from realizing most of their potential are their very low permeabilities and the paucity of potential reservoir rocks.
Low permeability has prevented migration of most of the free hydrocarbons from their site of origin in the shale matrix into nearby reservoirs. This retention of generated hydrocarbons has retarded the further generation of hydrocarbons within the shale, particularly the liquid (oil) ones, over much of the basin. Where there is fracturing, the shales themselves provide both source rock and the reservoir, and allow generation to proceed. In some cases, contiguous or interbedded siltstones provide small reservoirs, and the fractures provide migration channels through which the hydrocarbons move for relatively short distances.
This geochemical data synthesis gives direction to future selection of sites for stimulation research projects in the Appalachian Basin by pinpointing those areas where the greatest volumes of gas are contained in the shale matrix.
Another accomplishment of the geochemical data synthesis is a new estimate of the total resource of the Appalachian Basin. The new estimate of 2,500 TCF is 25 percent greater than the highest previous estimates. This gives greater incentive to government and industry to continue the search for improved stimulation methods, as well as for improved methods for locating the sites where those improved stimulation methods can be most effectively applied.