bluuebunny/crossref_metadata_2025_split huggingface dataset:
Simplified Strength Analysis of Jack-Ups
Authors: Carlsen C. A. , Odland J. 
Published: December 2007

ABSTRACT
New challenges are posed on structural analysis of jack-ups when moving to deeper water, more harsh environment and application high tensile steel. Dynamic behaviour becomes more prevailing and fatigue due to wave loads may become governing. Furthermore, supply boat sizes tend to increase and they work in more severe weather conditions, increasing the risk for collisions with the jack-up legs.
The present paper describes simplified ways to cope with the effects above.
Development of the thin Oil Zone Underlying the Snapper Gas Field
Authors: Seage N W , Lau J , Koh S T 
Published: December 2007

ABSTRACT
This paper describes the successful development by Esso Australia Ltd (Operator) and BHP Petroleum Pty Ltd of the Snapper field which is located in the Gippsland Basin beneath the waters of Bass Strait off south-eastern Australia. Discussion is focussed on the development of a thin, "pancake" type oil column of 4 to 8 metres thickness which underlies the Snapper N-1 gas reservoir. The gas reservoir, which has a maximum gross thickness of 208 metres, comprises very high quality sandstones with interbedded shales, siltstones and coals.
A 27 conductor production platform has been installed in 55 metres of water with facilities for concurrent production of gas and oil. The timing of the development has permitted successful development of the thin oil column before major withdrawal of gas takes place.
Development of the oil zone was complicated by the presence of interbedded non-net sections which, combined with the varying thickness of the oil column provided significant well targeting challenges. Several high angle wells were required for oil production which presented drilling and logging problems. However, 16 of the 21 wells drilled succeeded in intersecting oil columns suitable for production. Performance of the oil wells has been very encouraging, but also variable with a wide range of producing GOR's, water cuts and wellhead pressures.
Thin oil columns of 2 to 15 metres overlying water and underlying a large gas cap are common within the Gippsland Basin and elsewhere. Snapper, the first development of one of these oil zones in the Gippsland Basin, has provided valuable and encouraging experience in performance of the wells, completions and surface equipment. This will assist economic assessment and facilities design for other with thin oil column development prospects.
Field Development Planning For The Semangkok Field Offshore Pen Insular Malaysia
Authors: Khandwala S.M. , Rani Abd Malek Abd , Rahman Mohd Nasir Abdul 
Published: December 2007

Abstract
In the Semangkok field the hydrocarbon-bearing formations are two sandstones which contain rim type oil accumulations. The paper discusses the seismic and exploration drilling carried out for field delineation and other studies conducted to determine an optimum reservoir development strategy. The discussion includes the geology, preliminary development assumptions, and use of symmetrical element numerical models to determine the number of wells, well locations and initial completions, and the recommended reservoir depletion plan. Selection of the optimum development plan included geologic uncertainty, facilities options and interrelations plan included geologic uncertainty, facilities options and interrelations of the two oil sandstones.

Introduction
The Semangkok field is located in the South China Sea, 35 kilometers off the east coast of Peninsular Malaysia in a water depth of 64 meters (Figure 1). Esso Production Malaysia Inc. (EPMI) has explored the field and is developing it as a contractor to Petroleum Nasional Berhad (PETRONAS), the Malaysian national oil company. The field is scheduled to go on production in 1984.
The structure that contains the field is an east-west trending anticline that is cut by faults at both ends. The field is located in the downthrown western fault block of the Semangkok anticline. The hydrocarbon-bearing reservoirs are Late Miocene group E sandstones that contain rim-type oil accumulations with associated gas caps. Commercial quantities of oil are found in two of the sandstone units in this field. These two primary reservoirs, E-6/16 and E-34/36 sandstones, are interpreted to be delta plain bar and channel deposits. Group E strata consist of sandstone, plain bar and channel deposits. Group E strata consist of sandstone, siltstone, shale, and coal sequences of marginal marine environments.
Two detailed reservoir simulation studies using symmetrical element models have been carried out to optimize the proposed field development plan. These major modelling efforts have enabled selection of optimum well location and spacing, initial completion, and reservoir drive mechanism. The reservoir models were also used to quantify the effects of reservoir heterogeneity, aquifer strength and benefits of gas injection and recovery efficiency for the field.
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Measurement Uncertainty in the Determination of Weight and Centre of Gravity of Large (Offshore) Modules, Using Strain Gauge Load Cells
Authors: Tegelaar P 
Published: December 2007

ABSTRACT
When measuring the mass and the co-ordinates of the centre of gravity of a large structure, reliability, reproducibility and measurement accuracy are increasingly important. The various items that affect the measurement accuracy will be discussed. A method is given for the determination of an overall uncertainty, starting from errors that cannot be eliminated by proper corrections, in combination with the statistical uncertainty of the measurements.
A standardized weighing procedure is described, underlining stable and reproducible loading conditions to get good statistical reliability.
The state of the art in the best attainable measurement uncertainty is given.
A Worldwide Survey of Floating Production Facilities, Applications, and Future Possibilities
Authors: Hammond G. R. 
Published: December 2007

ABSTRACT
In June 1975 Hamilton Brothers started production in their Argyll Field in the North Sea. Besides being the first offshore production in the U.K. sector, the project ushered in a new trend – the floating production system. Since that time the interest in the cost, schedule and flexibility of floating production systems has increased dramatically.
This paper will look at the advantages of a floating system over a fixed platform concept, and survey where installations have been made. Comparisons will be made between the various types of installations, and concepts for the future will be reviewed.
Associated Gas Utilisation in Sabah, Malaysia
Authors: Kia Tan Ek , Sikchi K G 
Published: December 2007

ABSTRACT
Based on extensive studies and planning, the State Government of Sabah are now investing the equivalent of 1 billion US Dollars in a gas utilisation project which will stop the venting of associated gas produced offshore Sabah and broaden the state's economy base.
The project involves the installation of new platform facilities adjacent to existing oil production platforms in the Samarang and Erb West fields for collection, processing and transmission of up to 90 mmscfd of gas to the island of Labuan where gas will be utilised by a 47MW combined cycle power plant, a 2000 ton/day hot briquetted iron plant and a 2000 ton/day methanol plant presently under construction.
The project is targetted to come on stream second quarter of 1984.
A New Technique in Sand Control Using Liner Vibration with Gravel Packing
Authors: Solum J. R. 
Published: December 2007

Abstract
Vibration of the liner in shop tests and field gravel completions illustrates the substantial difference achieved in compaction of the gravel. The standard gravel pack results in cubic packing' of the gravel whereas the liner vibration technique results in hexagonal packing. This achieves a denser more stable pack with an average 15% to 25% more gravel in the same volume. Vibration eliminates the fluid placement to the formation to achieve compaction with viscous aqueous polymer completion fluids. Also, this method of vibration has eliminated liner washing which stops the comingling of the formation with the gravel. Liner vibration is now being used extensively in development wells and also for completions in injection, steam and gas storage wells.
Steam Condensate: Formation Damage and Chemical Treatments for Injectivity Improvement
Authors: Amaefule J. O. , Padilla P. C. , McCaffery F. G. , Teal S. L. 
Published: December 2007

Abstract
This paper discusses the results of laboratory studies conducted to determine the potential for formation damage from alkaline condensates during steam injection in a reservoir in the San Joaquin Valley, California. The paper also reviews various remedial treatment options and recommends some optimal treatment injection sequences to sustain steam injectivity.
Laboratory flow tests conducted in field core plugs with condensates at different steam qualities reveal the tendency of the condensates to dissolve the rock, destabilize the clays, and hence reduce the permeability. The alkaline condensates from once-through steam generators were also found to be incompatible with the formation water, and thus had the potential to form calcium carbonate precipitates and scales.
Pretreament of boiler feeds and/or concurrent treatment of boiler effluents with either a low concentration (&lt;0 .1 % wt.%) phosphoric acid in 2 % potassium/ammonium chloride solution or 2 % ammonium dihydrogen phosphate reduced silica dissolution, stabilized the clays and rendered the condensates more compatible with the formation water.
Determination of Rock Properties by Quantitative Processing of Geophysical Borehole Logs
Authors: Peveraro R. C. A. , Cable H. W. 
Published: December 2007

ABSTRACT
Geophysical well logs can be used to determine subsurface lithological units. Currently available methods generally provide only qualitative descriptions based on crossplots of two well logs. Comprehensive error analysis within this method is not possible, so some information can be misinterpreted. Other investigators have proposed specifying the well logs as a linear system responding to the proportion of each lithology component. Signal processing and information theory techniques can then be employed to quantitatively determine these components and their associated errors. The general form for this system is L = CV, where L is the geophysical log response vector, C is the response coefficient matrix, and V is the lithological component proportions vector. Solutions are obtained for all combinations using under-determined, determined, and over-determined systems. The error computation allows the initial model to be modified and the results further improved.
This technique can be generalised to include the computation of bulk volume estimates viewing the well logs as a linear system responding to variation in all geophysical parameters. It should, therefore, be possible to estimate from the solution of the general system not only the proportions of the lithological elements but also the proportion of the fluids filling the pore space. Known non-linear responses can be eliminated by prior processing or by appropriate linearisation models of. log responses. This is particularly required for resistivity and acoustic measurements.
Phase Behavior and Dense Phase Design Concepts for Application to the Supercritical Fluid Pipeline System
Authors: Hankinson Risdon W. , Schmidt Thomas W. 
Published: December 2007

ABSTRACT
This paper presents a summary of the work performed and the results obtained to determine the feasibility, from phase-behavior considerations, of operating a supercritical, single-phase pipeline to transport NGL rich gas through the Norwegian North Sea. The experimental and computational objectives of the study were:
To provide experimental benchmark points to validate the computational models for dew points, cricondentherm, and vapor densities. To test the ability of both the Peng-Robinson and the Phillip-Soave equations of state to model rich gas behavior in the retrograde regions. To provide visual demonstrations of the retrograde phenomena and the formation and disappearance of liquids with isothermal changes in pressure.
Effects of Supercritical Carbon Dioxide on Well Cements
Authors: Onan D. D. 
Published: December 2007

ABSTRACT
Due to the widespread manifestation of large scale miscible CO2 enhanced recovery projects, particularly in West Texas and Gulf Coast regions, considerable concern has developed regarding the performance and/or durability of hydrated cement located across producing and injection intervals in CO2 related wells.
It is known that carbonation affects the micro-structure of cement affecting both porosity and compressive strength. The CO2 reactivity of a cement is characterized not only by its chemical composition, but also by the properties of the CO2 medium itself, that is, partial pressure, temperature and relative humidity. However, a clear understanding of this phenomenon and its effects on portland cement is still not completely substantiated, giving rise to contradictory opinions in this particular area of research.
This led to the need and development of a laboratory program for examining the effects of supercritical CO2 on preset cement, as well as the influence of carbonation on the early stages of the cement hydration process. This article presents the findings of a comprehensive study which show that after prolonged exposure to CO2 under supercritical conditions, the hydration products formed in the hydration of common portland cement undergo decomposition into calcium carbonate and a siliceous residue. Cement samples exposed to the lower extremes (temperature and pressure) of a supercritical CO2 environment exhibited greater reactivity under dynamic conditions as compared to static conditions, while increasing CO2 pressure increased the degree of reaction regardless of the carbonation conditions employed.
Injectivity Improvement in the Grayburg Formation at a Waterflood in Lea County, NM
Authors: Martin F. D. 
Published: December 2007

ABSTRACT
The purpose of this project was to improve water injectivity into the Grayburg formation at MORANCO's Rice-Hardin Waterflood in Lea County, NM. The project was a cooperative effort between the Petroleum Recovery Research Center, the New Mexico Petroleum Recovery Research Center, the New Mexico Energy and Minerals Department, the New Mexico Energy Research and Development Institute, and MORANCO of Hobbs, NM.
Laboratory tests with reservoir cores were conducted at the Petroleum Center. These tests indicated that certain chemical treatments had the ability to increase water permeability about 30%. The treatments were designed to reduce the oil saturation in a region about 8 to 10 feet out from the injection wellbore, and to improve injectivity by increasing the relative permeability to water.
Two of the most promising treatments were selected for the field trial. Rice No. I injection well was treated with a surfactant solution, and Hardin No. 3 was treated with an aromatic solvent followed by a surfactant solution. Costs of chemicals were approximately $3,000 per well. As a result of these treatments, slightly more water could be injected at pressures 400 psi less than the before-treatment levels. Since improvement in flow efficiency, observed from the injection rate and pressure data, is on the order of 50 to 60%, the field treatments apparently worked somewhat better than indicated by the laboratory tests.
Based on the encouraging results obtained from the trial, these concepts should have applicability in other waterflood projects and may also have potential in certain enhanced recovery projects where low injectivity is a problem. projects where low injectivity is a problem.
Liner Rotation and Proper Planning Improve Primary Cementing Success
Authors: Hyatt C. R. , Partin M. H. 
Published: December 2007

ABSTRACT
Throughout the industry's history, successful liner cementing is one of the most difficult operations associated with drilling and completing of oil and gas wells. When utilizing liner rotation while cementing with proper displacement mechanics, it is possible to obtain an optimum liner cement job. Employing recent tool development and cementing techniques with proper displacement mechanics will result in more successful primary liner cement jobs. This paper presents an improved liner cementing technique. State of the art equipment, its historic development, design, and recommended procedures are discussed. Theory, test results, and field experience of displacement mechanics are combined to illustrate the relative importance of proper planning to displace drilling mud from the annulus.
Pressure Transient Analysis in an Elongated Linear Flow System
Authors: Ehlig-Economides C. A. , Economides M. J. 
Published: December 2007

ABSTRACT
The prominent examples of linear flow behavior in the well test literature relate to linear flow within or to a fracture penetrated by a producing well. The resulting pressure transients generally are exhibited in the early portion of a well test and are followed by infinite-acting radial flow behavior and/or boundary effects.
In this paper, the linear flow occurs in the formation, which has a predominantly linear shape. Analysis of interference, drawdown, and build up tests is described in theory and illustrated by practical examples. The necessary equations for the analysis are provided for testing gas, geothermal steam, and oil wells.
In elongated linear flow systems, the pressure transient behavior associated with linear flow occurs late in the drawdown or build up test. The type curves provided in this work show that this pressure behavior is readily distinguishable from conventional well tests, particularly in interference tests.
The Effect of Stratification, Fractures, and Dip on Steam Sweep Efficiency and Heat Requirements of Steamflood Operations
Authors: Abad B. P. , Hensley C. A. 
Published: December 2007

ABSTRACT
A one-phase, thermal simulator has been utilized to study the applicability of steamflooding in different reservoir geometries.
Two and three-dimensional numerical models of homogeneous dipping (0°, 15°, 30°, 45°, and 60°), heterogeneous dipping (0°, 30°, and 45°), and fractured dipping (0°, 30°, and 45°) reservoirs have been developed. The parameters investigated were heat utilization, steam vertical and areal sweep efficiency. The simulator was also utilized to generate temperature profiles for different reservoir types at different injection times. Results of this study show that dip and/or fractures should not be considered detrimental when screening reservoirs for steamflooding. Heat utilization and vertical sweep efficiency are not significantly affected by dip. Formation heterogeneities tend to control steam displacement in a reservoir more-so than dip does. Natural or induced fractures improved the steam sweep efficiency but at the expense of heat utilization. Averaged (over the upper, middle, and lower section of the reservoir) steam areal sweep efficiency improves with dip and/or fractures, and for extended injection periods the observed differences become less significant.
Mine-Assisted Heavy Oil Recovery Technology
Authors: Harding T. G. , Farouq Ali S. M. 
Published: December 2007

ABSTRACT
A summary is made of technical considerations in underground mine assisted production of oil sand as well as a review of field experience in Canada and the U.S.S.R.
An assessment is made of future prospects for the application of such technology. It is concluded that although the technology exists to construct underground shafts and tunnels, and that mine assisted methods are well suited to certain oil reservoirs, these reservoirs may not be developed in the short term in preference to other more economically attractive projects. It is also concluded that, because of large lead times required for technology development, research and development activities, and in particular piloting work, should continue in the near term in order to establish methods and experience for certain large deposits.
Heavy Oil Mining Technical and Economic Analysis
Authors: Lyman T. J. , Piper E. M. , Riddell A. W. 
Published: December 2007

ABSTRACT
U.S. Department of Energy studies have indicated that the United States has produced only about one-third of its estimated reserves of heavy oil, primarily because this oil is unrecoverable by conventional production methods. One technology that shows promise for recovering these reserves is oil raining. Of three fundamental mining methods, surface extractive mining, underground extractive mining and underground mining for access, the surface extractive mining and underground mining for access methods appear to be technically feasible for oil recovery.
Two heavy oil reservoirs are used as the basis for an economic evaluation of the two technically feasible mining methods. These two reservoirs were selected from an extensive list of heavy oil reservoirs in the United States based on a favorable combination of physical characteristics including depth, net pay thickness, oil saturation in barrels per acre, reservoir area, and total estimated reserves. The Kern River Field, Kern County, California was used as the basis for an economic evaluation of oil production using surface extractive mining methods. The McKittrick Field, Kern County, California was used as the basis for an economic evaluation of oil production using underground mining for access methods.
The economic evaluation of surface extractive mining was based on a mine plan capable of producing approximately 38,000 barrels of oil per day for a 20 year project life. The economic evaluation indicated that surface extractive mining would require an oil selling price of $27.26 per barrel to produce a 20 percent return on investment. This evaluation included capital and operating costs for mining, processing, and disposal of the processed oil sand ore.
The economic evaluation of underground mining for access was based on a mine plan capable of producing between 10,000 and 20,000 barrels of oil per day for a nine year project life. The mining for access method was determined not to be economical without thermal assistance because capital and operating expenses were not fully recovered over the project life due to low oil mobility. The economic evaluation indicated that mining for access with thermal assistance would require an oil selling price of $43.25 per barrel to produce a 20 percent return on investment. This analysis indicates that lighter oils with higher mobility offer better potential for successful economic demonstration of mining for access technology.
Offshore Drilling with Preformed Stable Foam
Authors: Hall D. L. , Roberts R. D. 
Published: December 2007

ABSTRACT
Preformed stable foam has proven successful in drilling many onshore underpressured or fluid-sensitive formations, however, its use in offshore applications to date has been limited. Recently two redrills were completed offshore in the Santa Barbara Channel with stable foam. Because the operation was performed offshore, it offered new challenges.
The use of foam in conjunction with a downhole mud motor in directional drilling was a concern, as no data was available. Since foam is not recirculated, its disposal, particularly given the limited platform space and environmental considerations, was a major challenge to overcome.
Two wells were redrilled where lost circulation had occurred in past conventional redrill programs. A preformed stable foam program was designed to meet the offshore lost circulation, well deviation and directional needs.