bluuebunny/crossref_metadata_2025_split huggingface dataset:
The Revamp of Two 20-Year Old Drilling Platforms
Authors: En Lee Yin , Fullbrook Roger 
Published: December 2007

ABSTRACT
The Ampa-1 and 2 platform complexes, installed in the mid 60s in 75 ft. water depth, were the first major offshore developments in the S.W. Ampa Field, 8 miles offshore Brunei.
In order to continue production and allow further development of the offshore South West Ampa oilfield reserves the original drilling and production platforms of the Ampa 1 and 2 Production complexes required replacement or major repairs because of general deterioration.
This paper describes the Ampa 1 and 2 Revamp project and the conclusions drawn from its successful completion with special emphasis on the technical achievements and safety precautions.
Implementation of the Malaysian Peninsular Gas Utilisation (PGU) Project
Authors: Salleh Hashim 
Published: December 2007

ABSTRACT
The paper will discuss the philosophy and strategy in the implementation of the first stage of the Malaysian Peninsular Gas Utilisation Project. The focus will be on project management, technology transfer, local participation and the lessons from the experience. The project is implemented in three stages. Stage I, which involves the processing and delivery of gas within Terengganu is now completed. Stage II, which involves the piping of gas to the power stations in Port Kelang and Port Dickson and southward to Singapore is under initial implementation. Stage III, delivery to the north, will be implemented later.
Start-Up Experiences : North Rankin ‘A’ Platform
Authors: Glass Peter W 
Published: December 2007

ABSTRACT
The North Rankin 'A' Platform has been in operation since May 1994 following an eighteen month period of Hook-up and Commissioning. This paper provides a summary of the organisation and activities associated with Hook-up, Commissioning and Start-up of the Platform Facilities and provides a number of examples of lessons.learnt from the Start-up process. Furthermore, significant ongoing problems and where relevant, their solutions are also highlighted.
A Correlation for the Viscosity of Light Normal Paraffin Hydrocarbon Systems
Authors: Gonzalez Mario H. , Bukacek Richard F. 
Published: December 2007

This paper was prepared for the 41st Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to held in Dallas, Tex., Oct. 2–5, 1966. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
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 graphical correlation of the viscosity data for normal paraffin hydrocarbons and their mixtures based on a pseudo-molecular weight is presented. The correlation reproduces experimental viscosity data for pure component, binary, and multi-component normal paraffin hydrocarbon systems with a standard deviation of +-5 per cent. The formula used to calculate the pseudo-molecular weight is presented together with a graphical representation of the correlation and tables of the smoothed values given by it.

Introduction
The existing data on the viscosity of hydrocarbon mixtures at high pressures are scarce and there exists a need for methods to enable estimation of the viscosity of these mixtures under the conditions of their production and processing. This paper presents a g graphical correlation for the viscosity of single and multi-component hydrocarbon systems. Special attention has been paid to that range of molecular weight in which the naturally occurring multi-component systems fall. The correlation represents a simple method of predicting the viscosity from a knowledge of the temperature, pressure and composition of the hydrocarbon system involved.

Background
The viscosity of hydrocarbons at pressure near atmospheric has been extensively studied over a wide range of temperatures. Less work has been devoted to the study of the pressure effect on viscosity, particularly because of the experimental difficulties involved. The scarcity of the available data and the infinite number of possible mixtures, either naturally occurring or man-made, have prompted several authors to investigate the use of theoretically or empirically derived correlations to generalize the existing data. The basis for these efforts have been either the assumption of simple molecular models, or selective use of the available data on a limited number of systems. The kinetic theory approach advanced by Enskog has been the most widely used theoretical basis for correlations. Discussions on the subject, together with proposed equations following this approach have been given by Colburn, Drew, and Worthington, Lype, Gardner, and Woolley, Scott and Brickwedde.
Modeling 4D Seismology
Authors: McDonald J. A. , Gardner G. H. F. , Tatalovic R. 
Published: December 2007

Abstract
The 3D (or areal) seismic technique has become more widely used as an exploration tool in the oil industry. Originally the technique was devised because it was recognized that geological features are, in the main, three-dimensional. The conventional planar CDP method could generate generalized regional information but out-of-plane data are not correctly imaged.
It soon became apparent that the 3D method could provide a means of mapping the areal extent of acoustic discontinuities in the subsurface. In addition it was seen that if the areal seismic data could be tied to data from at least one well in the area in the form of a VSP, not only the area but the volume of the discontinuity could be determined. It is therefore evident that 4D seismology (measurements in the x,y,z and t directions) can provide a very suitable and economical tool for determining the extent of a hydrocarbon accumulation prior to enhanced oil recovery.
The main problem with applying the techniques of 4D seismology to the real world is that the results can only be checked with the drill; a very expensive procedure. In addition the resolving power of the surface seismic method in measuring the simplest stratigraphic traps is barely understood. Therefore, the Seismic Acoustics Laboratory of the AGL at the University of Houston has initiated a research program in which 4D seismology techniques are being modeled physically. The aim is to provide the industry with some measure of the tool as an aid to enhanced oil recovery projects.
This paper will show some of the first measurements of the resolving power of the areal seismic method and how the resolving power can be affected by the geometry of the data collection and by the nature of the wave propogation in the media surrounding the hydrocarbon accumulation.
Causes of Problems and Losses in Petroleum Loans
Authors: Ryan Robert S. 
Published: December 2007

This paper was prepared for the 41st Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to held in Dallas, Tex., Oct. 2–5, 1966. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
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
The objective of this paper is to learn more about why problems occur in oil and gas loans and what steps may be indicated to prevent or minimize future problems.
A survey, to which 30 institutions active in oil lending replied, furnished data and causes for 134 problem oil loans, Eighty-four of the oil loads cited are problems because of slow repayment and fifty of the cited loans have involved (or will involve) some degree of loss. A computer technique was developed to analyze the data and the resulting information about causes of problems in petroleum loans has not been hitherto available or previously published.
An analysis of the data shows the dominant causes for problem oil loans were:
Reserve estimates were too high Rate of production was forecast too high One Held loans (Lack of Diversification) Operators' financial failure Operators' failure to perform
Reserve errors, rate errors, and one held loans all seem to rank equally as dominant causes of problems. Reserve errors and production forecast errors are clearly engineering reasons and stand out throughout the survey findings. Other cause factors such as proration forecasts, market prices, and gas sales level aid not show up as significant causes of the problems reported on the survey.
The survey findings show that small lending institutions have had somewhat higher, loss experience than larger institutions. There also appears to be a relationship of higher loss experience with increasing size of the lenders' oil loan portfolio.
The paper discusses reasons for the results revealed by the survey findings and makes recommendations of methods to achieve more rigorous engineering analysis to prevent or minimize future problems.

Introduction
This paper is an outgrowth of a study which was prepared for the Graduate School of Credit and Financial Management at Stanford University.
Selection of Nonionic Surfactants for Minimized Adsorption and Maximized Solubilization
Authors: Lewis S. J. , Verkruyse L. A. , Salter S. J. 
Published: December 2007

Abstract
Adsorption values for mono-isomerically pure nonionic surfactants are shown here to depend upon the phase properties of the surfactant in aqueous solution. When the experimental conditions are referenced to the temperature at which the solution being employed phase separates, the adsorption values over a range of temperature, brine salinities and surfactant concentrations are observed to follow a consistent trend. This correlation is observed to be consistent for six surfactant molecules, over a range of solubility balance, both with and without aromatic rings. The observations reported here indicate that for applications requiring a particular optimal temperature, large linear ethoxylated alcohols are preferred to either smaller molecules or phenolic species.
Wilmington Field Steam Operations
Authors: Teberg J.A. 
Published: December 2007

This paper was prepared for the 41st Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to held in Dallas, Tex., Oct. 2–5, 1966. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
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
Cyclic steam injection into wells producing low gravity oil has proven to be the most important stimulation method used in the Tidelands area of the Wilmington Field since waterflood. Substantial oil rate increases and very favorable economics are resulting from the steam injection program.
Oil rate increases of five to ten times are very common and may be sustained at three to four times the level of former production. Peak production rates, both gross and net, often exceed new well rates. Large lease areas as well as producing wells are rejuvenated by cyclic steaming.
Experience has indicated that oil can be recovered at or below per barrel cost when compared with pre-steam production rates. Therefore, production operations benefit from steam stimulation by the combination of rapid pay-out, low per barrel operating cost after pay-out and much less time for oil recovery. The timing for re-cycling is a very important factor in order to operate at minimum cost for oil recovery.
Cyclic steam injection was started in the Tidelands area in the Wilmington Field in February 1965. The initial injection site on Pier B included fourteen wells producing from the Tar zone, Fault Block V. This area was considered to be the most ideally suited for steaming because of the low gravity oil (12 deg to 159 API), low water cuts, high structural locations and favorable reservoir characteristics as well as a convenient surface location. Since the start of the project more then sixty wells have been steamed in the Tidelands.
Production after steaming may decline rapidly, however, the rate normally levels out considerably above the pre-steam production rate. Results obtained by re-steaming are definitely encouraging and show that the oil rate may be returned to the level stimulated by a previous steam cycle with a slower decline rate and greater economic benefits.
Effective stimulation by steaming is attributed to the lowering of viscosity of the oil by heat and to well bore clean-up. The effects of well bore clean-up appear to be the most important contribution to success, at least for the first cycle.
Well Stimulation by CO2 in the Heavy Oil Field of Camurlu in Turkey
Authors: Bardon C. P. , Karaoguz D. , Tholance M. 
Published: December 2007

ABSTRACT
The Camurlu oil field, operated by the Turkish Petroleum Corporation (T.P.A.O) in Southeast Turkey, contains roughly 60 millions m3 (380 MMbbl) of a low gravity oil (10–12° API) in the "Alt Si nan" formation.
The poor quality of the oil, the heterogeneity of the reservoir and the presence of a large gas cap are responsible for the low primary recovery estimated at less than 1%.
The "Mus" formation, located beneath the oil-bearing reservoir, contains a CO2-rich natural gas (73%).
In 1983, these facts have led TPAO and the Institut Français du Pétrole to evaluate the stimulation of oil production wells with the CO2-rich gas using the Huff n'Puff technique. Two production wells, located as far as possible from the gas cap were selected at first.
The tests which started in 1984, consisted in the injection of a limited amount of CO2 (11 MMscf) followed by a short soaking time and a subsequent back-production. Early oil production figures showed a more than 5 fold increase over figures obtained prior CO2 injection.
This paper presents the results obtained on the two wells selected for the pilot test. Up to now two cycles of injection-production in each well have been performed.
Finally, the planned extension of the project to other wells is presented.
A Progress Report on Polymer-Augmented Waterflooding in Wyoming's North Oregon Basin and Byron Fields
Authors: DeHekker T. G. , Bowzer J. L. , Coleman R. V. , Bartos W. B. 
Published: December 2007

ABSTRACT
Marathon Oil Company has implemented two large full-field polymer augmented waterflood (PAW) projects in Wyoming's mature Rig Horn Basin oil producing area. These projects are well under way and are designed to improve the waterflood sweep efficiency in the Embar and Tensleep Reservoirs of the Byron and North Oregon Basin Fields. The observed production response of the two projects has resulted in the expansion of the PAW projects to other Big Horn Basin fields where further significant contributions to increased incremental tertiary production and reserves are expected.
This paper discusses historical secondary and recent tertiary production performance along with operations of the injection, production, and treating systems since commencing PAW operations. Also, laboratory work, field testing, PAW implementation and certification are presented.
Design and Analysis of a 30-in., 3,000-psi Blowout Preventer
Authors: Allen M. B. , Preston J. P. 
Published: December 2007

Abstract

Subject
This paper describes stress analysis methods and results used to evaluate and improve the design of a new blowout preventer. A 30 inch, 3000 psi blowout preventer had not been previously manufactured and the design procedures involved extrapolation of experience with smaller designs. To evaluate the new design and eliminate the need for testing prototypes, finite element stress analysis was performed on the original design and subsequent design modifications. The stress analysis ensures that stresses and deformations in the BOP under expected test and service conditions are within generally accepted values and conform to standards of the ASME Boiler and Pressure Vessel Code.
A coarse finite element model is used to determine nominal stresses in the BOP and identify high stress regions. Refined models are used to determine stresses in critical areas. Results of the analysis were used to reduce the overall weight by removing steel from low stress areas and adding steel to regions that required additional strength to satisfy fatigue life design criteria. The size of the BOP and the pressures it must withstand result in deformations larger than those typical of smaller designs. Accurate calculations of these deformations were important to determine if a particular seal design is sufficient. The large span also results in greater variations in flange bolt loads and contact stress around the ring gasket than what occurs in other designs.

Significance
Most existing blowout preventers have been designed with hand calculations and prototype testing, before finite element analysis techniques became widely available or accepted. The subject of this paper is unique because of the size and pressure rating of the BOP and because computer models were used to thoroughly evaluate the design prior to any physical testing.
Risk Reduction Through Quality Management of Critical Service Well Equipment
Authors: Armstrong G. M. , Brown D. H. , Reynolds W. W. 
Published: December 2007

Abstract
High strength, heavy wall, controlled yield or corrosion resistant alloy pipe and equipment are normally required for the complex operations and higher risks associated with deep, high pressure or corrosive environment wells. They may also be specified for wells in environmentally sensitive areas and wells with other critical circumstances. These components frequently require a level of quality assurance which can be provided only through execution of a centralized, integrated quality assurance program. This type of program, using a systematic approach to overall quality assurance, ensures that the appropriate items are ordered, manufactured, inspected, tested and delivered in compliance with the required specifications and schedules.
This paper discusses Quality Assurance Project Management (QM) as a means of planning and executing a quality assurance program from initial procurement specifications through final installation. The basic QM Elements are defined and explained. Typical examples, showing the application of QM to critical service well components, are included. Additionally, the effectiveness of the Quality Management approach is demonstrated through specific examples of failure prevention and cost avoidance.
Dehydration of Heavy Crudes by Electrical Means
Authors: Lucas Roy N. 
Published: December 2007

This paper was prepared for the 41st Annual Fall Meeting of the Society of Petroleum Engineers of AIME, to be held in Dallas, Texas, Oct. 2–5, 1966. Permission to copy is restricted to an abstract of not more than 300 words. Illustrations may not be copied. The abstract should contain conspicuous acknowledgment of where and by whom the paper is presented. Publication elsewhere after publication in the JOURNAL OF PETROLEUM TECHNOLOGY or the SOCIETY OF PETROLEUM ENGINEERS JOURNAL is usually granted upon request to the Editor of the appropriate journal provided agreement to give proper credit is made.
Discussion of this paper is invited. Three copies of any such discussion should be sent to the Society of Petroleum Engineers office. Such discussions may be presented at the above meeting and, with the paper, may be considered for publication in one of the two SPE magazines.

Abstract
Operating data and results from a number of commercial installations employing chemically-aided electrical dehydration to purify low gravity (less than 18 degrees API) crude oils (including those produced by thermal recovery methods) are reported. The influence of certain physical properties of the crude oils - including API gravity, viscosity, and particle size distribution of the water droplets in the emulsion - on the results achieved by commercial units has been investigated and is described in detail. Similarly, the influence of certain operating conditions - including temperature, pressure, and electrical potential - is reported.
A description of the design procedure by which the electrical requirements, capacity, and product quality expected of field installations are calculated from laboratory pilot tests is included, as is a discussion of the means by which appropriate chemical aids are selected. A brief discussion of the role of chemical aids in electrical dehydration is also provided.
The data and results presented indicate that field installations can be satisfactorily designed on the basis of the physical properties of the crude oils and pilot plant tests when these elements are combined with appropriate empirical data. Both field data from operating units and laboratory tests also demonstrate that, with suitable equipment and operating conditions, the electrical dehydration characteristics of thermally produced oils do not differ significantly from those of other heavy oils.

Introduction
Background. Electrical dehydration was one of the earliest commercial means of dehydrating the heavy viscous crudes produced in California.
Laboratory and Field Applications of the Strain Relaxation Method
Authors: El Rabaa A. W. M. , Meadows D. L. 
Published: December 2007

ABSTRACTOver the past few years, the Strain Relaxation (SR) method (or the anelastic strain recovery) has been used for predicting the orientation of induced hydraulic fractures in oil wells. Reliability of the method requires a sensitive measuring device and cores free of natural cracks.A SR device that uses DC displacement transducers was developed and tested in laboratory and field conditions.An extended version of the SR method is suggested for laboratory use to predict directions and magnitudes of the in-situ stresses. In the laboratory, effects of pore pressure and natural fractures on SR data are investigated. It is observed that jacketed cores that have been subjected to hydrostatic pressure, expand in all directions on the release of the pressure, and that unjacketed porous cores subjected to the same pressure contracted in all directions during their relaxation period. Agreement between the laboratory azimuth predicted by both type of tests is observed.The calculated fracture direction suggested by SR data collected through testing cores which contain natural fractures is likely to be perpendicular to the maximum horizontal in-situ stress, thus the calculated direction will be 90° away from the true direction. On-site, the SR method is applied in three different wells. Results from two wells are in a fair agreement with predictions of other fracture orientation detection techniques.