bluuebunny/crossref_metadata_2025_split huggingface dataset:
The VASPS Subsea Separation and Pumping System Applied to Marginal Field Developments
Authors: Baker A. C. , Entress J. H. 
Published: December 2007

Abstract
A series of studies has been undertaken in order to quantify the benefits of various alternatives for the remote production of subsea oil reservoirs. Subsea separation and pumping appears to have significant advantages for remote production over longer distances and particularly in deep water when compared to alternative technologies such as multiphase pumping. The concept involves the separation of gas and liquids at or near the wellhead; with the liquids being pumped in single phase back to shore, or to a remote production facility, and the separated gas flowing back to the same location under wellhead pressure.
A novel separation and pumping system has been conceived which allows an integrated separator and pump to be installed within a conventional 30" conductor in a dummy well. This novel configuration has been called VASPS (Vertical Annular Separation and Pumping System).
A detailed series of hydraulic studies has been undertaken which indicate that the system is capable of producing over distances up to 100 km and that well deliverabilities are significantly enhanced at increased water depths. The authors believe this to be a significant conclusion as there is an increased economic incentive to employ remote subsea production in deep water.
Electrical Submersible Pumps in Subsea Completions
Authors: Scott P. A. , Bowring M. , Coleman B. 
Published: December 2007

ABSTRACT
Electrical Submersible Pumps (ESP's) are being utilised on production platforms as a method of artificial lift for enhanced recovery of oil. With more subsea fields being developed, it is apparent that there will be a demand for this technology in subsea completions. This paper presents the technical issues involved with the installation of ESP's in a subsea completion and describes a system for low cost installation and recovery of the ESP without the requirement to recover the tree. The system utilises existing workover equipment and techniques to provide a safe environment for atubing orcable suspended pump application.
Getting More Out of Drilling Data by Analysis-While-Drilling
Authors: Hytten N. , Havrevold L. , Parigot P. 
Published: December 2007

ABSTRACT
To ensure a safe and optimized drilling operation a number of parameters are continuously monitored through drilling instrumentation systems, MWD and mud logging services. It is up to the driller, the supervisor and the service personnel to analyze these parameters to ensure appropriate actions at the right time throughout the drilling operation.
This task has become more and more demanding due to the increased complexity of the rigs, more difficult drilling conditions and to the increasing number of parameters to be analyzed. Efficient and accurate manual interpretation of the drilling data has become an overwhelming task, and accidents and drilling problems do occur.
The use of a real-time computerized analysis tool for drilling data not only has proven that problems can be detected earlier and hence avoided, but also helps in gaining a better knowledge and understanding of the drilling operation itself, thus improving the overall performance of the operation.
This paper describes an expert system project that has developed into a full commercial service activity (AWD - Analysis While Drilling), now being offered on a worldwide market as a natural extension of today's MWD and mud logging services.
Single-Stack Wellhead System for Jackup Drilling Rig
Authors: Allen D. W. , Kelly J. H. , Omsberg N. P. 
Published: December 2007

ABSTRACT
Phillips Petroleum identified surface wellhead and blowout preventer (BOP) nipple up and nipple down time as an area where significant improvements in safety and savings in rig time could be made on the Audrey field in the southern North Sea UK sector.
With a view toward future use on central North Sea high-temperature, high-pressure exploration and development wells drilled from heavy jack-up rigs, a unitized wellhead system designed for use with a single 18-3/4" BOP stack and a mudline suspension system has been fabricated and used successfully on three development wells on the Audrey Phase II Project and on one exploration well in the southern North Sea.
Development of an All-Metal-Sealing Subsea Wellhead System for Critical Service Applications
Authors: Singeetham S. P. , Valka W. A. 
Published: December 2007

ABSTRACT
This paper discusses the design and results of extensive prototype testing of an all metal sealing, weight set, 18-3/4"-15,000 psi subsea wellhead system. This system (Figure 1) has been developed to meet industry requirements of higher pressure and higher temperature in critical applications.
Since the all metal-to-metal sealing packoff is critical to the reliability of the system, emphasis is given to its design and testing. Seal energization and retrieval forces are minimized by the unique seal design. Additionally, the development of an alternative elastomer packoff for use when all metal sealing is not required is discussed. The computer optimized hanger design addresses the need for increased system capacity.
An Environmentally Superior Replacement for Mineral-Oil Drilling Fluids
Authors: Friedheim J. E. , Hans G. J. , Park A. , Ray C. R. 
Published: December 2007

ABSTRACT
Environmental constraints have led to the development of an invert mud system which has excellent toxicity, health and safety aspects, and is biodegradable. This system is particularly suitable for North Sea use where discharges from drilling with mineral oil-base drilling fluids are limited. Based on a synthetic material as the continuous phase, this mud system gives the same high performance as that of mineral oil-base systems. This paper describes this novel mud system and focuses on the impact of its use in environmentally sensitive areas.
The ratio of synthetic liquid continuous phase and aqueous phase (S/W ratio) can vary from 90/10 to 50/50 with mud weights ranging from unweighted to 18.0 ppg. The rheology parameters can be altered with rheology modifiers to give increased low-shear-rate viscosities for enhanced hole cleaning capabilities. Huxley-Bertram HTHP viscometer data shows good stability of the system under downhole conditions. Additional work indicates this system has reduced gas solubility, better lubricity, and lower retention on cuttings when compared to mineral oil-base muds.
Favorable toxicity data, bioaccumulation studies, and biodegradation work have been compiled for both the synthetic material and mud system. U.K. toxicity tests give highly acceptable values. These results, along with the bioaccumulation data, have led the U.K. Department of Energy (DEn) to assign the system a Category 0 classification under its Chemical Notification Scheme. Likewise, the Norwegian government agency (SFT) has agreed to permit this system to be used on a field trial basis. Currently, the U.S. Environmental Protection Agency (EPA) is considering its use, and subsequent discharge of cuttings, for Gulf of Mexico drilling.
Design of Environmentally Safe Drilling Fluids: Tests Under Actual Bottomhole Conditions in an Original Flow Loop
Authors: Degouy D. , Lecourtier J. , Marcassa F. , Forsans T. 
Published: December 2007

ABSTRACT
Numerous additives are now available for designing water-based drilling fluids but in most cases the best conditions for their implementation on fields and their limits of use are poorly documented. This paper presents a comparative study of performances of additives provided by different manufacturers for high temperature well drilling. New environmentally safe drilling fluids usable at temperatures up to 160°C have been designed using the best additives and their performances have been characterized using an original flow loop recently developed by IFP.
This equipment enables the evolution of drilling fluid properties, including HP-HT rheology and static and dynamic filtration, to be characterized inside the loop during aging under actual bottomhole conditions of temperature (180°C), pressure (500 bar) and shear (10000 s-1).
The results indicate that the selected formulations performed satisfactorily during these tests and their field use is now planned. Moreover, these tests provide data allowing field operators to improve predictions and control of the behavior of commonly used additives under downhole conditions.
An Environmentally Acceptable and Field-Practical, Cationic Polymer Mud System
Authors: Retz R. H. , Friedheim J. , Lee L. J. , Welch O. O. 
Published: December 2007

ABSTRACT
With increasing environmental constraints on the use of mineral oil-base muds, attention has turned towards water-base systems. Recent studies have shown that cationic polymer mud systems exhibit a superior degree of inhibition when compared with other water-base muds. Previous considerations of these mud systems were troubled by high toxicity and operational problems. A newly developed, field-practical, cationic polymer mud system gives excellent shale inhibition without sacrificing environmental acceptability.
Cationic polymers provide more effective shale inhibition by attaching to the negatively charged clay surfaces more strongly than anionic polymers. However, formulating practical drilling fluids using cationic polymers is difficult as they tend to react with bentonite, anionic polymers, and weighting agents causing severe flocculation and precipitation. This can cause problems with product compatibility and high mud weights.
Shale encapsulation using this new system is provided by a high molecular weight polymer while swelling inhibition is achieved by using a low molecular weight polymer and/or inorganic salts. Acute aquatic toxicity tests show this cationic polymer mud system is much more environmentally sensitive compared to those previously used. The product incompatibility problem was overcome so that common additives such as bentonite, anionic polymers, and barite can be added for controlling filter-cake quality, fluid loss, and mud weight, respectively. The stability of the system is maintained using non-ionic polymers. Laboratory studies show that the new cationic polymer mud system is considerably more inhibitive than conventional water-base muds.
Measurement of Multiphase Well Fluids by Positive Displacement Meter
Authors: Gold R. C. , Miller J. S. , Priddy W. J. 
Published: December 2007

ABSTRACT
The paper describes a novel positive displacement flowmeter developed to measure the mass and volumetric flowrates of multiphase crude oil fluids in flowlines. After an introductory review of the technical and economic incentives for the development - particularly offshore and subsea, the paper goes on to explain the hydrodynamic problems that hitherto have inhibited the use of conventional metering techniques for multiphase flow measurement.
The paper then describes how these problems have been resolved by a novel combination of simple, well tried principles. The design concepts of the new meter are outlined, together with a brief review of its development from conception to the completion of endurance and calibration tests on two field trial meters. Special features of the positive displacement mechanism design, which enable the meter to withstand rigorous multiphase flow regimes, are explained. Field trial results confirming the meter's capability to resist such conditions are reported, as are the results of independent checks of its measurement accuracy, assessed over a wide range of flow regimes and void fractions. Comparison is made between the performance of the meter and that of a test separator system.
The New UK Oil and Multiphase Flow Measurement Standards Laboratory
Authors: King N. W. 
Published: December 2007

ABSTRACT
The paper describes the new UK Standard for Oil and Multiphase Flow Measurement being built at NEL to replace an existing, smaller laboratory. As well as having a greater single-phase capability, the standard will also include an oil/water/gas multiphase flow measurement standard to meet the needs of the new multiphase flow meters currently being developed. The first of the new flow facilities will be available later this year and all facilities will be fully commissioned by early 1993.
Built as a service to the oil industry it is important that the new laboratory can meet the present and future, needs of that industry. This paper is therefore presented, firstly to inform the oil industry of the capabilities of the new UK Standard for Oil and Multiphase Flow Measurement and, secondly, to invite comments and suggestions from all those with an interest in oil and multiphase flow measurement.
Retardation of Cement Slurries to 250°F
Authors: Bensted J. 
Published: December 2007

ABSTRACT
Examination of Class G cement slurry retardation up to 250° F has indicated that commonly employed retarders usually give a threshold of unexpectedly long thickening times at ~160-190° F BHCT. Normally, thickening time is not linearly but exponentially dependent upon retarder concentration. The causes of the threshold of long thickening times have been investigated by carrying out appropriate hydration experiments on Class G cements at water/cement ratio 0.44 subjected to thickening under different API Schedule conditions. The cause of the threshold effect has been found to be surge in hydraulic reactivity of the ferrite (C4AF) phase from the Class G cement. The hydration products thus formed, mostly AFt phase or ettringite C3(A, F).3CaSO4.31-32H2O, are deposited on the hydrating clinker surfaces and in particular impede the hydration of the main cementitious alite (C3S) to calcium silicate hydrate (C-S-H), the initiation of which is the prime cause of cement thickening. As a result thickening time is extended and not diminished. However, as the temperature rises above ca 190°F, the increased hydraulic potential of the cement manifests itself. There is no longer an increased surge in ferrite phase hydration to obstruct C-S-H formation, so the C3S hydration rate rises again, culminating in lower thickening times once more. The threshold effect has important implications in cement slurry design.
Emulsion Cement
Authors: Skalle P. , Sveen J. 
Published: December 2007

ABSTRACT
Gas leakage through cement in the annular space around a cemented casing is still a serious problem although new additives and improved techniques have reduced the problem. A new approach is the construction of an emulsion cement, consisting of a double emulsion; water-in-oil-in-cement. Waterdroplets containing a controlled number of species are emulsified into mineral oil. This W/O emulsion is then emulsified into the cement slurry in small amounts (3-15 vol %). The effect of the emulsion on the cement slurry has been recorded through standard API tests. In addition the bond between cement and steel surfaces and the tightness against gas migration have been checked. Compared to other cement slurries, the emulsion cement shows promising results with respect to becoming a friction reducer and an anti gas migration additive. Further tests are necessary to determine the applicability of emulsion cement. Cement slurries behave different at high temperatures, and test procedures and test equipment must be improved in order to comply with down hole conditions.
The Don Field: A Flexible Approach to the Development of a Marginal Field
Authors: Richardson S. M. , Blackburn N. A. , Shere A. J. 
Published: December 2007

ABSTRACT
The Don Field lies in the north-east comer of Block 21 l/18a approximately 15km north of the Thistle Field. The reservoir comprises the Middle Jurassic Brent group of sands and consists of several discrete hydrocarbon accumulations.
The appraisal well data portrayed a complex hydrocarbon bearing structure with considerable uncertainties regarding the degree of faulting, reservoir quality, connectivity and hydrocarbon fluid properties. This pointed to a phased sub-sea development tied back to the Thistle platform, which would allow for systematic reduction of risks, balancing of cash exposure, and lead ultimately to an optimum reservoir management strategy for the field.
First oil flowed in October 1989. Initial performance of the first wells has shown the Don NE reservoir to be highly faulted, and divided into a series of poorly connected compartments. This complex structure severely reduces areal sweep, and recovery from the initial wells will be considerably less than originally predicted.
The paper discusses how the development well results and production monitoring have led to a revised reservoir description of the field. The flexible nature of the Don concept has allowed the development strategy to be modified to accommodate the outstanding reservoir uncertainties, whilst maintaining sufficient production to make effective use of the current facilities.
Fluid Distribution in the Beryl Reservoir
Authors: Erga R. , Knutson C. A. 
Published: December 2007

ABSTRACT
The Beryl Formation, the primary reservoir in the Beryl Field, has a complicated distribution of pressures and fluids. Horizontal permeability restrictions, the result of extensive faulting, subdivide the reservoir into eight inter-related areas as determined by careful analyses of pressure histories, production histories and fluid monitoring. This paper decribes the methodology for constructing a conceptual reservoir model for the Beryl reservoir to identify areas of unswept hydrocarbons, resulting in an aggressive drilling programme, and optimise the effort in simulation history matching.
An Alternative for Shallow Water Oilfield Development in Arctic Waters
Authors: Gaida K. P. , Loh J. K. S. , Mitton F. E. , Pidcock G. A. , Wright B. D. 
Published: December 2007

ABSTRACT
This paper outlines the potential for low cost, shallow water, oilfield development in Arctic waters with equipment that has been utilized in the Canadian Beaufort Sea. A bottom founded structure, Molikpaq, designed and used for year-round Arctic operations, is described along with highlights of previous deployments in the harsh Beaufort Sea environment. The operational flexibility and capability of this structure for use within a range of Arctic offshore development alternatives is discussed, including modifications to the structure for increased production capacity and various transportation options. Cost estimates for these Molikpaq deployment alternatives are also presented so that the application of this proven Arctic technology can be assessed across a range of reserves.
Ivanhoe/Rob Roy Flexible Riser System
Authors: Smith S. N. , Mercer I. L. 
Published: December 2007

ABSTRACT
This paper describes the Ivanhoe/Rob Roy dynamic flexible riser system. The design requirements and considerations are summarised and a general description of the system is given. The paper then concentrates on giving details of the main components involved, thus presenting information on various aspects which are needed to turn theoretical knowledge and techniques into a viable system.
Flexible Risers for J-Tube Pull-In
Authors: McGennis E. , Fleming P. 
Published: December 2007

ABSTRACT
Flexible pipe has been used in a number of recent North Sea projects to upgrade existing platform facilities. This has been done by pulling flexible pipe up through J-tubes to create a new flow path to the top-side facilities. This has eliminated the cost of retrofitting a new riser caisson, and so it can be an economic alternative for the developments which involve a tie back to a host platform. With the increasing interest in this application of flexible pipe, this paper is put forward as an overview of some of the points that have influenced the pull-in projects completed to date.
Tool of the 90's To Optimize Gas-Lift Efficiency in the Gonelle Field, Gabon
Authors: Lemetayer P. , Miret P. M. 
Published: December 2007

ABSTRACT
This paper presents a new method, successfully implemented in March 1990, of operating Gonelle field wells in Gabon. Permanent actions of a programmable logic controller in respect to an expert logic ensure continuous production of the wells with a minimum gas injection rate.
A sharp production increase has been possible despite a simultaneous decrease in gas consumption.
New Water Injection Technology
Authors: Graff O. F. , Nielsen N. 
Published: December 2007

ABSTRACT
Water injection facilities are now used more frequently on offshore platforms to maintain reservoir pressure and hence maintain the oil production capacity and increase oil recovery. The injection of large amounts of treated seawater at high pressure into the reservoir traditionally requires considerable equipment space and power. The system operating weight will also be high.
The development of new fields at increasing water depths has encouraged the use of new technology. The development of topside systems with high efficiency and light weight is thus a challenge for platform designers and equipment suppliers. The water injection system for the Snorre TLP represents a significant advance in the system design, resulting in considerable space savings and a weight saving of about 560 tonnes.
The Snorre Water Injection Facility is the first of a new generation of systems. Cartridge filters which are cleaned by means of sulphuric acid are used for fine filtration of the seawater. The deoxygenation of the seawater is carried out in a two stage nitrogen stripping unit, reducing the oxygen content to below 10 ppb without chemical additives. Vertical injection pumps were also selected eliminating the traditional booster pumps and lube oil system. A full scale test of this unique system was carried out in the summer 1990. Test results showed that all parts of the system were operating satisfactorily and within the design specification.
Tethers 2000: Advances in Offshore Tether Technology
Authors: Casey N. F. , Holmes R. 
Published: December 2007

ABSTRACT
This paper demonstrates work being conducted which will result in advances in the technology of offshore tethering products; steel wire rope, synthetic fibre rope, chain and welded tubulars. The work will have major implications for the improvement of operational safety and discard criteria for mooring tethers. The objective of the paper has been achieved by discussing NEL's current involvement in several major studies and presenting an overview of the research conducted. This research has generated testing of the highest quality through the development of test assessment criteria and gained an insight into the fatigue behaviour of the tether products through the widespread use of condition monitoring techniques.
Reservoir Engineering Aspects of a North Brae Horizontal Well
Authors: O'Byrne D. K. , Fleming C. H. , Prentice D. 
Published: December 2007

ABSTRACT
The North Brae field is the first offshore gas condensate field in the North Sea to be developed by gas cycling for pressure maintenance and improved recovery. Withinthe reservoir the fluid composition changes with depth from a lean gas near the top to an oil rim at the base of the hydrocarbon bearing reservoir in low permeability conglomerate.
This paper details the design and production performance of a horizontal well completion within the oil rim of the North Brae reservoir. The well was completed at a true vertical depth sub-sea of 12405 feet with a perforated horizontal section of 1400 feet in August 1990 and produces condensate at a rate of about 10,000 BOPD.
A multidisciplinary approach to well planning is presented along with results of performance prediction by numerical simulation.The paper gives an insight to the practical aspects of planning such novel completions in the North Sea operating environment.