bluuebunny/crossref_metadata_2025_split huggingface dataset:
The North Sea And The UK Economy - A Financial Analysis
Authors: Johnson Christopher L.M. 
Published: December 2007

Abstract
The paper covers oil and gas in the United Kingdom and Norwegian sectors of the North Sea. It summarizes an economic and financial research study which the author is conducting. Statistics are given up to end-1977, with future projections. The oil and gas extraction industries are subjected to economic and financial analysis. The effects of the income generated for governments and oil companies are examined in terms of flow of funds and national accounts. The main subject headings are: Reserves, Production, Prices and Values, Energy Policy, the State Oil Corporations, Offshore Investment, Finance, Banking and Insurance, Taxation, Company Sector, Public Sector, Balance of Payments, Gross National Product. Policy decisions are assessed, and future policy options set out.

INTRODUCTION
This paper sets out to describe a research study in which the author is engaged. The project is not yet at the stage where firm conclusions can be put forward. The procedure adopted will therefore be to describe the methodology, and to give tentative findings wherever this is possible. Since many of the approaches employed in the study cannot be pursued in detail, further avenues of enquiry may suggest themselves to other researchers.
The general title of the study is "North Sea oil and gas and its economic significance". It is to be published by the Financial Times in late 1978. A number of economists have already published work in this area. References are given at the end of this paper. Three different lines of enquiry have been pursued in other work, which are all to some extent present in the author's study:An economic and financial analysis of the oil and gas industries themselves, taking into account their growing relative importance in the economies of the UK, and even more, of Norway.Taking the oil and gas industry as given, it is possible to follow the progress of the income which they generate into the different sectors of the British and Norwegian economies, and attempt to forecast how it may affect the balance of payments, the Government budget, or the private sector.A possible variant on 2) is to attempt a normative rather than a positive study, discussing various alternative uses of North Sea income as an exercise in political economy.
The author's study attempts to combine aspects of all three approaches. Comparisons are made, where they are appropriate and possible, between the UK and Norway, on both oil and gas development, and on the broader economic issues. Emphasis is also placed on how the oil companies will, or should, dispose of their North Sea income, as well as on the question of the allocation of Government royalty and tax income. Particular attention is paid to the two State oil companies, BNOC and Statoil, where both Government income and oil company income are involved. Gas is covered as well as oil, and the importance is underlined of achieving clarity in both statements and statistics as to whether oil only is being referred to, or also gas, and if so, whether it include Southern as well as Northern gas.
The Use Of Accurate Pressure Data In A High Permeability Environment
Authors: De Boer Engelbart Theodore 
Published: December 2007

Abstract
The advance of accurate pressure sensors with surface read-out facilities, has enabled a sufficiently accurate definition of both the time and pressure scales to allow for a detailed data analysis. Especially in a high permeability environment reliable information about the continuity and transmissibility of the reservoir and the pressure as a function of time can be obtained. The facility to read-out the measured pressure data instantaneously at surface allows optimisation and modification of test programmes during execution, resulting in a minimum of lost oil production and a maximum of information. Because of the integrity of the data and the reservoir characteristics, it proved possible to quantify the water influx rate into the reservoir with a single early pressure survey within narrow limits.

INTRODUCTION
In offshore deep water environments with a platform development programme the number of wells is strictly limited. Consequently, it becomes very important to extract the maximum amount of information from the reservoir on a per well basis.
For an extremely permeable and continuous reservoir, such as the Piper field, conventional pressure sensors frequently lack the accuracy to allow the determination of basic reservoir parameters. The productivity index and static pressure are often the only data obtainable.
Precision pressure sensors, such as the quartz pressure gauge, with an electronic time measurement device define the pressure and time scales sufficiently for a detailed data analysis. A range of different types of pressure tests can be devised to obtain specific information deemed necessary.
Due to the accuracy of the data, all the results of the analyses should be consistent. An adherence to first principles is required as otherwise wrong conclusions may be drawn from the observed pressure changes. To illustrate this, three pressure tests conducted in the same well will be discussed in detail.
Early evaluation of any water influx is of prime importance for future operations planning. In the particular case of the Piper field, the existence of a water drive appeared to be likely only two months after production started. It proved possible to quantify the aquifer influx rate within narrow limits with a single pressure survey after only four months of production.
Frigg, The First Giant Gas Field In The Northern North Sea
Authors: Dufond R. , Laffont M. 
Published: December 2007

Abstract
The development of the Frigg gas field is unique in many ways:It is the first giant gas field, to be put into production, in the deep and hostile waters of the northern North Sea, and at a considerable distance from the UK coast (360 kilometres).It is situated in both British and Norwegian offshore sectors.Production will be built up gradually to 1.5 billion CFPD of gas, which will represent, 40% of the present gas production of the six British gas fields of the southern part of the North Sea.The development scheme of this huge gas field has been prepared with the safety of the personnel, and the importance of the continuity of gas production in mind:The living quarters-control-platform is separated from the production and treatment platforms.There are two drilling-production platforms and two treatment platforms.
Therefore the consequences of a major accident are reduced: a minimum number of the personnel is exposed to danger and the supply of gas to the British Gas Corporation could be continued in the event of such an accident. This gas supply is vital to British industry.
After a general presentation of the main characteristics of this Field, and the problems related to the unitization between the British and Norwegian Sectors, the concept of this Field as a unique development will be given, as well as the description of each platform.

INTRODUCTION
The Frigg Field is the largest natural gas structure in the northern part of the North Sea and one of the giant offshore gas fields in the world. It was discovered in Norwegian waters, block 25/1, by Elf-Aquitaine Norge in June 1971, and the following year Total Oil Marine drilled the first well on its adjoining block 10/1 in the UK sector and confirmed the extension of the structure into British waters.
Drilling Without Conductors Piper Field Development
Authors: Trendall T. 
Published: December 2007

Trendall, T., Occidental Petroleum (Caledonia) Ltd. UK

Abstract
Occidental discovered the Piper field in the UK of the North Sea, 100 miles east of Wick on block 15/17 in January 1973. After the discovery well, another six wells were drilled to delineate the field. Early on in the appraisal drilling programme, it was decided a single steel platform with twin drilling rigs would effectively develop the field. The size of the platform (one of the largest steel platforms set in the deepest water at the time of setting) caused Occidental to develop a unique concept to help decrease the live loading on the platform construction and development drilling and helping speed initial production start-up. Experience gained from the exploration programme helped Occidental decide that it would be possible to develop Piper, utilizing a redesigned 20 in. string as conductor and doing away with the 30 in. string altogether. This concept was then incorporated into the final design of the platform.
PIPER DEVELOPMENT HISTORY PIPER DEVELOPMENT HISTORY The Occidental consortium's interest in the British sector of the North Sea shifted to activate exploration in 1970 following the Ekofish discovery in the Norwegian sector. On the basis of 20,000 miles of seismic data. Occidental placed application for British North Sea blocks with the government in 19712. In March 1972, the government awarded Occidental a petroleum licence for six blocks covering approximately 316,000 acres. Two months after the award. Occidental spudded its first well block 15/11. It was dry. The second well was drilled on 14/19 (Claymore) this was also a failure although shows were encountered. The third well was spudded on 15/17 (Piper). This well had to be abandoned at 750 ft due to weather conditions getting the better of the drill ship used. A new semi-submersible rig. The Ocean Victory, was acquired and this rig spudded 15/17-la in November 1972. This well flowed at a combined rate of about 90,000 bopd and the field was designated Piper field.
Underwater Repair Of Concrete
Authors: Humphrys B.G. 
Published: December 2007

Introduction
To carry out a satisfactory repair it is essential to obtain accurate details of the damage and establish the cause of the failure; with this information it is possible to develop a method of repair to prevent or delay future damage. In this paper consideration of methods of repair of concrete paper consideration of methods of repair of concrete permanently underwater and in the splash zone is related permanently underwater and in the splash zone is related to offshore gravity platforms and the damage that may occur on such structures; however, the repair materials and techniques can be used for any underwater concrete construction.

DAMAGE
Damage may be caused by accident, unexpected structural movement, failure or inadequacy of materials or workmanship in conjunction with hostile environmental conditions. The repair of such damage will have to fulfil one or more of the following tasks:Prevent corrosionRestore full structural strengthPrevent leakageMaintain or improve durability
which must be defined for developing the method of repair. The word 'cosmetic' is used loosely to describe a repair which does not restore full structural strength of the damaged area; the use of the word should be avoided because it is inappropriate and it is simple to properly define the particular requirements of a repair. The construction contractors and operators of platforms are naturally reluctant to make known details of platforms are naturally reluctant to make known details of repairs which may be needed to their concrete structures, Such information as can be gained indicates there have been some impact accidents which have reduced or removed the concrete cover to the rebars. It is known that there have been some problems of leakage through cracks during construction and installation stages. However, little has been heard of the type of damage most frequently observed on inshore construction which is the spalling of the concrete cover to rebars due to failure or inadequacy of materials and/or workmanship: no doubt this is due to the very high quality of the concrete and the attention given to this particular problem during the design and construction.
On Stream Inspection Of Pipelines
Authors: Osborn C.W. 
Published: December 2007

Introduction
'They don't make it the way they used to,' or words to that effect are often heard these days and invariably reflect sadness (or frustration) that the high standards of a bygone age are no longer applicable. The pipeline industry could perhaps use the same expression but the meaning would very different. The modern pipeline embodies a higher degree of technology and, in consequences, of safety, than ever before.
A glance at a map showing major pipeline systems gives some idea of the degree to which industry is committed to transporting an ever-widening range of raw materials and products. There are, however, a number of facets to this growth pattern which are under regular review.
Firstly, over the last 25 years standards have changed considerably. Pipelines built in this period have progressively taken advantage of the availability of new steels and new technology.
Secondly, fatigue stresses leading to brittle and ductile fractures have been closely studied along with many other operational factors affecting pipeline integrity.
Thirdly, the growing proximity of one pipeline service to another, in some cases involving use of a common wayleave, places a responsibility on each occupier with reference to the security of the other.
Fourthly, increased speeds and density of road, rail and air travel present a potential hazard to buried services.
Finally, expanding population and the decentralization of industry lessens the distance between major pipeline systems and populated areas.
So to some extent there is a conflicting situation - pipelines are designed and built to a better standard than ever before but may be subject to a greater hazard than previously envisaged. The pipeline industry is very aware of the problems and this paper is intended to cover only one aspect, that of irregularities in pipeline diameter.
Multifunction Support Vessel For North Sea Construction, Maintenance And Emergency Operations
Authors: Edwards W.R. , Jacquet E.K. 
Published: December 2007

Abstract
The basic requirements of marine vessels as stable working platforms in the North Sea has existed since commencement of exploratory drilling. This requirement has now expanded to include year round construction and maintenance for associated oil and gas producing platforms, and lately for emergency disaster and blowout control. During the development of the Occidental Petroleum Consortium's Piper and Claymoe fields, Petroleum Consortium's Piper and Claymoe fields, based on 56 vessel-months of construction support anchored adjacent to platforms, an on-going need was realized for a comprehensive marine vessel, outfitted to support these developments. The additional requirement of fire-fighting and disaster control resulted in the emergence of a uniquely designed semi-submersible multifunction support vessel (MSV). Occidental has now placed a keel-up order in a Japanese shipyard for 1979 delivery of this special unit. The specifications for the unit have been developed in conjunction with Redco Inc., and Earl and Wright, a subsidiary of Sedco Inc.
The requirements for such a multifunction support vessel are unique to the individual operations to be carried out, and specifications include those necessary for dynamic positioning, fire-fighting cranage and a comprehensive saturation diving system. Development of these specifications resulted in a dynamically positioned column stabilized semi-submersible vessel equipped with the following unique features:Extensive on board maintenance facilities for support of platform production and maintenance operations:A dynamic positioning system suitable to D.P.on all sides of a burning platform in Beaufortstate 10 while effectively fire-fighting.Fire-fighting equipment to provide for fire control platform abandonment, and remote manipulation and removal of debris associated with such disasters.A sixteen man saturation diving system, featuring a tethered and manned Mobil Diving Unit.
The Effect Of Confining Stress And Fluid Properties On Arch Stability In Unconsolidated Sands
Authors: Clearly Michael P. , Melvan Joseph J. , Kohlhaas Charles A. 
Published: December 2007

Abstract
A cylindrical sand pack, 52.75 inches long by 16 inches in diameter, was used to study the stability of unconsolidated sands across casing perforations. Bottom-hole producing conditions perforations. Bottom-hole producing conditions were approximated with overburden stresses of 250, 750, 1500, 2250 and 3000 psig. Fluid saturations consisted of an irreducible water phase and liquid hydrocarbons. The sand used phase and liquid hydrocarbons. The sand used was Gopher State 20/40 frac. sand, and the different hydrocarbon fluids investigated were kerosene and mineral spirits.
The observed mechanism of sand stabilization around a wellbore was the formation of sand arches across a perforation opening— an observation consistent with those instability was recorded at the moment of failure of sand arches.
Arch structure is a function of the stress distribution in a sand pack. Maximum arch size and stability were also found to be a function of confining stress. The effect of different hydrocarbons on arch stability manifests itself in the cohesive forces in the pendular saturation of the wetting phase at the arch wall. Dilatant restabilization of arches is accommodated at higher stress levels and it is greatly enhanced by the cohesiveness of the sand in the arch itself. The conclusions from this study both strengthen and extend knowledge of unconsolidated sand behavior.

Introduction
The ability to control sand production has been measured by the success of mechanical and chemical processes and devices; however, well productivity is severely reduced with each productivity is severely reduced with each measure taken to control sand production.
An alternative method of sand control is based on the premise that stable sand arches can be formed under the conditions present in an unconsolidated reservoir. Field observations verify that in several cases, a producing oil well in an undersaturated reservoir will initially produce small amounts of sand when it is placed on steam. Initial sand production then ceases, and sand-free oil production is maintained until wellbore parameters are altered.
Sand flow into the wellbore is generally thought to be a function of one or more of the following factors:Fluid drag associated with high oilviscosities.Fluid drag due to high fluidvelocity.Skin buildup around the wellbore.Rate surges.Changing loading conditions around the wellbore due to pore pressure around the wellbore.
In the past decade, several investigations have been made to understand sand arching more fully. Hall and Harrisberger observed that under a confining stress dry angular sand would readily form an arch. They also observed that a cohesive force resulting from a residual fluid saturation was necessary in a well-rounded sand to allow an arch to form.
Large-scale Application of (Anisotropic) Pre-stack Depth Migration in the Foothills
Authors: Johnson Peter , Doyle-Linden Andrew , Miller Susan L. M. , Martin Brian 
Published: December 2007

Abstract
Introduction
Shell Canada Limited is routinely applying full (anisotropic) Pre-Stack Depth Migration (PSDM) to 2D and 3D seismic surveys in the Foothills of Western Canada. In this paper we will show data examples which illustrate the practical application of these techniques. This technology can contribute to drilling success though proper well positioning and thus has important business implications.
Anisotropic 3D PSDM
In the highly structured fold and thrust belt of the Foothills, anisotropic clastic beds which are steeply dipping often overlay deeper carbonate targets. This can result in poor focussing and mispositioning of structures on the seismic section unless these effects are correctly accounted for in processing. The Shell Group has developed algorithms for anisotropic prestack depth migration which are being effectively applied by Shell Canada on both 2D and 3D Foothills data. Structures show improved focussing and, in some cases, lateral shifts on the order of 100 - 300 metres. The formulation of the Shell proprietary anisotropic PSDM is such that it is able to handle any symmetry of anisotropy. However, current experience is limited to working with the TI assumption, though also accommodating a laterally varying tilted axis of symmetry.
Practical considerations for PSDM
Shell's proprietary state-of-the-art processing management software (used worldwide by the Shell Group) deals with many of the logistical requirements for processing large amounts of data on a network of workstations. This has had significant impact on the turnaround achievable for 3D PSDM projects. It also frees up geophysicists to concentrate on geophysical issues, including velocity model building and updating, as opposed to administering jobs through the system. Thus quality PSDM processing is accomplished in a timely, efficient manner which is suitable not only for Development but also for Exploration needs. Though expertise is required to oversee the correct application of the technology, the whole system facilitates a staged progression of learning for personnel new to 3D PSDM, allowing them to quickly become productive.
Our PSDM processing software is tightly linked into Shell's proprietary 3D interpretation software (123DI) which provides a communication vehicle for processor/interpreter interaction on an ongoing basis from initial model development to intermediate results and model updates, to final product. This is a crucial link, the impact of which should not be underestimated.
Recommended Procedures for Utilizing High Cost, Non-Damaging Fluids
Authors: Ilfrey William T. 
Published: December 2007

ABSTRACT
Over the last six years nondamaging fluids, primarily inorganic salt blends, have proved to be very cost effective in numerous applications to drilling and production operations. A natural progression to high density, high cost non-damaging fluids has occurred. Successful application of these high cost fluids requires better planning and improved operational procedures, a better understanding of the physical properties of the fluids, and an evaluation of the optimum economic benefit of the fluid at project termination. The aim of the present discussion is to recommend a pre-operation planning procedure. A discussion of the physical properties of the fluids is presented to maximize the number of economic alternatives. The considerations governing whether fluid will be disposed, sold, or stored and reused are reviewed.