bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Approach to Production: The Elgin & Franklin Partnership Based Operation
Authors: Menou G. , Hearn P. N. 
Published: December 2007

Abstract
Elgin and Franklin fields will be operated by Elf Exploration UK plc (EEUK) in an environment quite different from earlier generations of North Sea developments. Production personnel are becoming increasingly exposed to fluctuating commercial pressures in the oil & gas industry and need to be prepared to respond to these. At the same time, more and more Operators consider some functions which are important to successful production as ‘non-core’ activities and look to contractors to provide and support these functions through contracts which motivate performance.
Not only are skills transferring between Operators and contractors but also technology is being employed to reduce the size of offshore crews. In addition, production from Elgin and Franklin will commence under a goal setting legislative regime, which increases pressure upon Operators to ensure that they have access to the right people to ensure safe and responsible operation.
In an environment where competition for people with the right mix of knowledge, experience and adaptability is strong, EEUK has adopted a strategy for operation and maintenance of Elgin and Franklin which will enable contractors to demonstrate their commitment to new ways of working. Some companies that have supplied critical equipment and systems, have been given the opportunity to be involved long term in the successful and safe production of gas and condensate.
This paper discusses how EEUK has considered the risks of trends in contracting strategy, which are relatively new to them as a company, and balanced these risks against benefits of new ways of working. Through development of a suite of contracts to support operation and maintenance of Elgin and Franklin, EEUK has recognised the need to obtain services from the most appropriate source. Performance measures and incentives, which are being established, take account of the responsibilities and commercial considerations of both EEUK and its contractors.
The paper concludes with a summary of lessons learned so far in implementing a strategy that requires EEUK to manage some complex contractual relationships when Elgin and Franklin enters its Production Phase in year 2000.
Design, Material and Installation Considerations for Ultra Deepwater Pipelines
Authors: McKinnon Colin 
Published: December 2007

Abstract
This paper discusses specific considerations and challenges associated with the design and installation of subsea pipelines in deep water with reference to recent relevant projects. Such considerations include mechanical design, construction techniques and parameters, as well as prevailing physical and environmental conditions. On-going developments and design approaches are discussed together with existing installation capabilities and a review of possible future developments.
Design of a Deepwater / Deephole Dynamically Positioned Semisubmersible Drilling Unit with a Purpose-Designed Column Configuration
Authors: Haavie T. , Stakkeland H. , Florvaag M. 
Published: December 2007

Abstract
Tensions, derrick and rig equipment weights generally act near the centre of semisubmersible drilling units. Deepwater/ Deephole drilling operations in 1,000 - 3,000 metres water depth and up to 12,000 metres hole depth, also require more tubular storage capacity on deck than work in water depths up to, say, 200-500 metres and hole depths up to for example 7000 metres.
The four inclined centre columns on the FE-P099 semisubmersible represent steel applied directly in the paths of the major global forces resulting from such centrally acting loads. Two additional functions of these comparatively large diameter columns, are as providers of major storage space for powder tanks and as significant hydrostatic stability contributors, which strengthen the total steel application advantage of the FE-P099 over other traditional units with vertical columns and small diameter bracing supports.
The application of steel in the right places and for more than a single purpose leads, in turn, to a lower steel weight, a lower lightship weight, smaller displacement, less required thruster power, a smaller total power plant and a lower price than for other vessels advocating similar deck load capacity and dynamic station keeping capability.
Progress Towards Zero Based Hook-up
Authors: Hume Ian 
Published: December 2007

Abstract
The paper sets out to chart the step change continuous improvements achieved in UKCS Hook-ups from 1992 through 1998. This process has seen the manhours/tonne required to Hook-up and Commission large (greater than 20,000 te topsides) offshore installation fall from an industry average of 75 manhours/tonne to less than 15 manhours/tonne (Fig. 1).
The change process has been complex and it has been necessary not only to challenge the technical sacred cows but also the philosophical, cultural and organisational core beliefs prevalent in our industry during this period.
The story is not complete yet. We believe that there are still significant activity level reductions to be delivered some of which we have already targeted and no doubt we or others will deliver yet more.
Primary Separation and New Generation of Interface Level Measurement Systems
Authors: Yang M , Hall A R W 
Published: December 2007

Abstract
There are a number of new technologies that have been developed for the purpose of monitoring the interface level, the thickness of emulsion and foam layers simultaneously. These include capacitance based using embedded sensors; ultrasonic based with two transducers operating in pulse-echo mode; and devices based on measuring the variations in fluids heat transport; as well as nucleonic with which a number of ways have been configured specifically for the application of subsea separation systems.
Most of these techniques are being currently commercialised. This paper is therefore to review the state of the art of these instruments and that in general of the interface level measurement systems for separators; and to examine the pros and cons for their applications to the industry.
Step Change in Drilling Efficiency in Mature North Sea Fields from New Motor and Bit Drilling System
Authors: Gaynor T. M. , Irvine G. T. , Boulton R. , Gilchrist D. A. , Lane Ian 
Published: December 2007

Abstract
The paper describes the improvement in drilling efficiency obtained in five mature North Sea fields, by using a systems approach. The drilling program was managed by a drilling efficiency group consisting of a service company, drilling contractor and operator engineers drawn from several disciplines. All of the well sections were geometrically complex. Data was gathered using downhole pressure and vibration sensors, and acoustic caliper sensors.
MWD annular pressure measurements had shown that conventional steerable motor/bit combinations required extensive circulation and occasional back reaming to ensure adequate hole cleaning. MWD vibration measurements and BHA modeling had proved that particularly high levels of vibration were caused by both circulating and back reaming. This was directly associated with MWD, motor and other downhole tool failures. It was concluded that the basic problem was hole quality and attention was directed to eliminating hole spiraling deduced from MWD logs and calipers.
A new combination of compatible steerable PDM and long gauge bit was designed with input from the operator. This was designed to achieve improved hole quality from long gauge bits without losing the rapid deviation response of conventional motor/bit combinations. The aim was to improve overall drilling system efficiency, particularly poor hole cleaning, excessive torque and drag, and slow ROP when sliding.
The paper discusses the initial data gathering and diagnosis and how measurement and modeling of downhole conditions led to the optimal solution. Comparison between 8 conventionally drilled hole sections and 8 hole sections drilled utilising the new drilling system showed more than 50% reduction in overall drilling time. Significant time savings have been made when drilling in the orientated mode. Other benefits are reduced drilling WOB from 30,000 lb to 3,000 lb, reduced drilling torque and drag, and an overall improvement in hole quality reflected by improved hole cleaning.
Coiled Tubing NDT Inspection: Implementation, Experience and Results
Authors: MacArthur J. , Shearer C. , Crabtree A. , Nelson R. 
Published: December 2007

Abstract
The use of Coiled Tubing in the workover and drilling sectors of the industry has seen considerable growth. This is due, in no small part, to the changes in tubing manufacturing techniques that have led to better materials and more consistent tubing performance. Consistency of tubing performance has enabled a large body of research work to be conducted in order to understand the low cycle fatigue and mechanical behaviour of coiled tubing in service.
When Coiled Tubing (CT) is used in oilfield applications it is subject to numerous plastic bending reversals which impose low cycle fatigue damage on the tubing. This damage is cumulative and leads to eventual failure - loss of pressure integrity and in some cases catastrophic failure. With the research work undertaken over the last several years the boundaries of the operating envelope have been better identified and can be predicted with the use of fatigue management computer models.
A result of this knowledge is that, as fatigue failure can be predicted for a given tubing and tubing material, other factors are becoming influential in some of the premature failures experienced in field operations. These factors are often found to be such things as manufacturing flaws, corrosion and mechanical damage.
To further enhance the reliability of CT in service it would be beneficial to detect such flaws before the tubing is run into a well when the cost of tubing failure can be expensive. Several non-destructive inspection (NDT) devices are becoming available on the market, each with their advantages and disadvantages. This paper summarises experience gained in the Canadian Oilfield by application of current NDT technology over the last 24 months and what alterations have been made to operating procedures as a result.
Added Value from NMR Measurements to Characterize Gas Reservoirs in the U.K. Southern North Sea
Authors: Epping W. J. , Eggenkamp I. M. , Reid I. 
Published: December 2007

Abstract
In our Southern North Sea gas reservoirs, we have acquired a number of Nuclear Magnetic Resonance (NMR) logs under various conditions. Nuclear magnetic resonance tools respond primarily to the fluids present in the reservoir. Objectives of NMR logging are: to improve permeability estimation in noncored wells and to quantify fluid volumes. In several wells the log interpretation was calibrated by NMR laboratory analysis on core. We interpreted NMR logs in-house using advanced tools developed by Shell.
The application of NMR logs in low to moderate quality gas reservoirs is widely regarded as challenging. Reasons for this are the low NMR signature of gas due to the combined effect of low porosity and a low hydrogen index.
Key findings of our work are:
If properly used, NMR tools confirm the interpretation by conventional tools and improve on permeability and fluid estimation. Some of our logging jobs could have provided more information with better planning (of acquisition parameters, tools and mud systems) and more experience available. Porosity and permeability by NMR are less dependent on core calibration than conventional derivation from porosity tools. Our in-house interpretation increased accuracy and insight into the reservoir.
In this contribution, we will report our experiences with NMR logging and interpretation and comment on the added value of NMR logging in lower quality gas reservoirs.
Optimising the Reservoir Management of Remote, Subsea Fields
Authors: Storer A. J. , Kelly R. T. , Fleming J. M. 
Published: December 2007

Abstract
As a result of field development in increasing water depth, technological advances and general project economics, subsea-developed accumulations are becoming more remote from the host infrastructure; furthermore, these accumulations are getting larger. This raises several problems for those concerned with longer term reservoir management of such fields, including limited well testing opportunities. The case study of a subsea development of several hundred Bcf of gas at a distance of 50 km from the host, offshore South Africa, demonstrates how through alliancing the reservoir and surface evaluation efforts, the conflicting strategies of maximising reservoir management data and minimising cost may be balanced.
Multilateral Well Utilization on the Increase
Authors: Vullinghs P. , Dech J. A. 
Published: December 2007

Abstract
Shell U.K. Exploration and Production (Shell Expro), in its effort to reduce the cost per barrel of oil, continues to foster the evolution and utilization of multilateral wells and associated new technologies to develop, both, new and maturing reservoirs in all sectors of the North Sea.
Multilaterals with TAML junction levels 1 through 4 have been applied in six fields to date and will be applied to an additional seven fields within the next two years. Multilateral wells have provided a means to optimize slot usage, commercially develop lower-quality reserves within the Brent sequence, and combine appraisal objectives with economical development targets.
This paper will show how Shell Expro has applied multilateral wells in field development using level 1 and 2 junctions in the Southern Gas Basin in the Southern North Sea and level 4 junctions in the Central and Northern Sectors. The complementary technologies of underbalanced drilling and intelligent well completions are being integrated to optimize field development.
Shell Expro is also a major proponent of the level 6 multilateral (sealed junction) that is being developed by the industry.
With the increasing maturity of the North Sea reservoirs, the need to produce new oil cheaper and quicker, and the instability of oil prices, multilateral well technology provides the industry with another tool to lower the cost of reserve development.
Energy Optimization on Offshore Installations with Emphasis on Offshore Combined Cycle Plants
Authors: Kloster P. 
Published: December 2007

Abstract
Increasing fuel cost and concern regarding emissions have incurred focus on energy conservation on offshore oil and gas installations. On the Norwegian continental shelf there has been an increased commercial value of natural gas and a CO2-tax on fuel consumption the last 10 years. For the time being the alternative value of natural gas is in the range 0 to 0.08 EUR/Sm3 and consumption of fuel is taxed with approx. 0.1 EUR/Sm3 burned. This has brought forward significant changes in operational procedures and technology development on the Norwegian oil and gas installations compared to installations in other oil and gas regions throughout the world. Focus has increased on keeping the power requirement down, avoiding unnecessary fuel consumption and designing more energy efficient systems. The most efficient way of achieving this is by installing cold process flares and steam cycles on existing or new gas turbines to form Combined Cycles (CC). In Norway three steam cycle plants fueled by gas turbine exhaust are under completion on offshore oil and gas installations. The overall electrical efficiency of these plants is around 50%. When steam is extracted for process heat the overall thermal efficiency is higher. Compared to conventional simple cycles the combined cycle reduces consumption of fuel gas and emissions of CO2 and NOX with minimum 25%. When designed as alternative to conventional simple cycle solutions, a combined cycle represents an alternative investment reducing the size and/or the number of gas turbines needed. This gives a good contribution to the overall Life Cycle evaluation in favor of the combined cycle option when compared to the simple cycle option.
The U.K. Offshore Operators Drill Cuttings Initiative: New Ways of Seeking Solutions
Authors: Faulds Eric C. 
Published: December 2007

Abstract
Drill activity in the Central and Northern areas of the North Sea has created deposits of drill cuttings on the seabed at the drilling sites. Many of these deposits are contaminated with oil used during the drilling process. The environmental significance of these deposits needs to be established and consideration needs to be given to the best environmental practice in dealing with this legacy of drilling activity. It is not known if the best environmental practice will be to leave the deposits in place or to remove them. If removal is the best option then equipment will need to be developed to do this. These issues have the potential to initiate a confrontation debate between the oil and gas industry, academics, regulators and environmental pressure groups. In recognition that such issues must be handled differently post Brent Spar the U.K. Offshore Operators Association have initiated a programme of research and development which will not only address the scientific and technical issues but will also involve all stakeholders in an open and transparent process to address the issues such that the Best Environmental Practice can be identified and the Best Available Techniques be developed. It is believed that the process being adopted by the industry is unique and could form the model for the resolution of other environmental and publicly sensitive issues.
Brent Field Depressurization Management
Authors: Gallagher J. J. , Kemshell D. M. , Taylor S. R. , Mitro R. J. 
Published: December 2007

Abstract
The Brent Field commenced production in 1976, with annual oil production peaking in 1984 at 410 Mbbl/d. Since the mid 1980s, oil production has been declining, but because of the high solution GOR substantial gas reserves remain, dissolved in the residual and bypassed oil. In 1992 the decision was taken to depressurize the Brent Field to recover an additional 1.5 Tscf of gas and 34 MMstb of oil, extending the field's life by 5-10 years. This would entail redevelopment of three of the four Brent platforms at a total cost of £1.3 billion to install process facilities for low-pressure operations, to reduce operating costs, to implement safety upgrades, and to refurbish facilities. The fourth platform was also upgraded but no low-pressure facilities were installed. Preparation of the platforms for long-term field development was completed at the end of 1997.
This paper addresses the processes and systems to measure reservoir performance against plan as depressurization of the Brent Field gets underway. By several measures, 1998 has been a year of significant change. The number of well entries, gas export, gross liquid production, and reservoir pressure change were all at their highest ever levels, whilst the field's oil production remained significant in U.K. terms.
Implementing the reservoir management strategy requires striking an appropriate balance between well activity which provides an immediate return on oil or gas production and well activity which is to produce mainly water in order to liberate gas for later benefit. Essential to the decision making process is the acquisition of surveillance data, of sufficient quality and coverage, to allow proper tracking of the rapidly changing field conditions. This surveillance data then needs to be translated quickly into meaningful information, such as graphical displays of oil/gas/water distribution and quantification of parameters such as free gas cap size. This information is compared with previous predictions, with the history-match being revised where necessary, resulting in continued refinement of the static and dynamic reservoir models. Accordingly, depressurization performance can be monitored against plan and variances recognised early, leading to the optimum response in production or investment profile.
The Machar Field, Unlocking the Potential of a North Sea Chalk Field
Authors: Brown Alastair , Davies Merv , Nicholson Hugh , Gane Brian R. 
Published: December 2007

Abstract
The Machar field is located in UKCS block 23/26a. BP Amoco operate the field as part of the ETAP (Eastern Trough Area Project) development. The reservoir is mainly low permeability (less than 1 millidarcy), fractured chalk. Production rates from appraisal wells in the 1980s and early 1990s were disappointing at 2,000 to 8,000 bpd, which reduced the economic attractiveness of developing the field.
The Machar Field is now under development and recent production wells have delivered flowrates in excess of 30,000 bpd. These improvements have been achieved by close and careful integration of all aspects of well planning and operations which have evolved over several years. This case history discusses some of the areas which have contributed to unlocking the chalk potential of the Machar field. These are, use of a phased development; optimisation of well planning, fracture identification and acid stimulation to provide highly productive wells.
Sharing Knowledge of Exceptional Achievements to Accelerate Change and Enhance Competitiveness
Authors: Brooks-Rooney Annette , Burnett S. , Keogh W. 
Published: December 2007

Abstract
Stretch Performance Network (SPN) was established in 1996 as a response to some of the key challenges facing the UK oil & gas industry:
sustained low oil prices environmental and societal pressures restructuring of the industry improving competitiveness
It was created by a group of individuals who share a common ethos about the value of learning in enhancing business performance and the quality of mutual respect necessary to support this concept. Members include Global Marine Integrated Services, BP Amoco, BG plc, Conoco, AMEC, Halliburton Brown & Root, Sema Group, Trident Consultants, Scottish Enterprise and OPITO.
SPN is a not-for-profit organisation that seeks to work collaboratively to improve the long term effectiveness and efficiency of the UK oil & gas industry and ensure its survival in an increasingly challenging and competitive environment. It aims to achieve this through:
the development and application of business transformation tools, processes and models which identify and capture achievement and learning store that knowledge and provide a means for sharing and exploitation among its Member network and beyond.
This paper will highlight the role of SPN, its integrated products, services and competencies, and will provide a case study of their application, outcomes and benefits.
START: What it Means to us All
Authors: Nystrom Mark F. , Senior Lewis M. 
Published: December 2007

Abstract
And so "building" a Safety Management System (SMS) for the organization will focus peoples’ energies on safe work practices, right? OK then - combine effective management of the system and the work place becomes safe, right? Getting closer granted, but why do incidents continue to happen despite elaborate and sophisticated systems in place to keep everyone safe and out of harms way? Perhaps there needs to be a refocus on people - the actual drivers of the system. Alas, close attention to how people behave, their actions, and inaction. Attention in the form of Observing! It seems that too many systems today are driving the actions of people instead of peoples’ action determining system direction. START is a process which produces positive results in peoples’ behavior through observations and positive feedback. It changes an organization's culture by changing peoples’ hearts.