bluuebunny/crossref_metadata_2025_split huggingface dataset:
Draft Contribution to Future Guidelines for Licensing of CO2 Storage In Saline Formations and Depleted Hydrocarbon Reservoirs
Authors: Groenenberg Heleen , Carpenter Mike , Flach Todd Allyn , Zink-Jørgensen Kim , Schröder Peter , Beck Brendan , Christensen Nils-Peter , Chatwick Andy , Lescanne Marc , Aimard Nicolas 
Published: October 2008

Abstract
In January 2008 the European Commission proposed a directive on the geological storage of CO2 in the EU. Simultaneous to the development of the directive by the EC, the CO2ReMoVe project, funded by FP6 and industry, wrote a Draft Contribution to Future Guidelines for licensing of CO2 storage in saline reservoirs and depleted hydrocarbon reservoirs. This document contains detailed checklists for operators and authorities in each of the stages of a licencing procedure for a CO2 storage operation. The draft guidelines will be updated as results from monitoring ongoing CO2 storage operations become available. They may serve as a contribution to the regulation of CO2 storage anywhere in the world, and may be also be of use in evaluating the EU directive in the future.

Introduction
The geological storage of CO2 provides a key element in mitigating CO2 emissions and contributing to the achievement of Kyoto (and successor) targets in a world where economic stability will depend on fossil fuels for the next several decades. The first step towards Europe's goal of becoming a hydrogen economy requires the manufacture of hydrogen from fossil fuels. This can potentially be done cost-effectively on a large scale without significantly reduced GHG emissions, if the resultant CO2 can be securely stored in geological formations.
Europe has invested large research efforts in CO2 geological storage monitoring in a number of storage scenarios, gaining experience with industrial-scale projects (Sleipner, Weyburn), and smaller-scale pilot projects (Ketzin, K12B, Kaniov). Two new industrial-scale geological storage projects (In Salah and Snohvit) now provide the opportunity to build on this work. For CO2 storage to qualify in Emission Trading Schemes, R&D efforts are required to develop a sound basis for monitoring and verification. This will provide the assurance of long-term storage security and establish consistent site certification guidelines for policy makers, regulators and industry.
ACG Topsides Design and Fabrication
Authors: Kearney Carroll Lee , James Mike , Nethercott Tim , Tate Geoff 
Published: October 2008

Abstract
The ACG Project concept basis was to deliver as few platforms with as many wellslots as possible, resulting in the delivery of four new drilling topsides facilities having a total weight of the order of 15,500 tonnes each, plus two injection support platforms weighing approximately 13,000 tonnes each. Integrated topsides for this size had never been fabricated in Azerbaijan.
The project was also challenged due to limited and out-of-date fabrication infrastructure and no in-country proven fabrication contractor capability for such topsides construction.
The solution was to establish a topsides production line approach to delivery, with the design being cloned from deck to deck underpinned by simplistic layouts for drilling and injection support topsides, respectively. Further, the installation of these decks would be via floatover installation method, thereby allowing the maximum amount of onshore commissioning with a minimum of offshore commissioning. All topsides fabrication would occur at two in-country fabrication yards, with the exception of the drilling facilities and the living quarters.
This paper describes the development of the topsides layouts, supporting engineering design, fabrication yard upgrades, cloning benefits and decisions associated with where and how fabrication could optimally be achieved.
The ACG topsides production line was successfully established and six topsides have been delivered offshore since start of fabrication in November 2001. As a result, similar production lines are being established on other developments.
The information in the paper will be of use to others who have similar large field offshore developments where full cycle delivery - from start of engineering design to start of production - can be optimised.
The production line approach, underpinned by standardisation of design, fabrication processes and people, proved capable of delivering deck-on-deck reductions in cost and schedule. The delivery can be improved further through the rigorous use of lessons learned feedback.
This project demonstrates the benefits of developing innovative solutions to overcome specific problems. These solutions were relevant in a part of the world that has not traditionally delivered facilities to shareholder standards.

Introduction
The ACG Full Field Development (FFD) Project began in 1997, but, due to a variety of economic and geopolitical reasons, the first phase of project sanction did not occur until September 2001. The chosen offshore development strategy involved three phases of incremental development - two large fixed offshore platforms for each phase (see Figure 1 at end of paper).
The Application of Similarity and Repeatability Premises in a FPSO Conversion
Authors: Barbosa Carlos Bartolomeu Bastos , Klein Mario Nigri , Machado Marco Tulio Pereira , dos Santos Aldemir Bonfim , Filho Joper Andrade , Guedes Fernando Pedrosa 
Published: October 2008

Abstract
This paper aims at discussing the main advantages of repeating a FPSO Project for different oil fields developed by PETROBRAS. It will also be discussed the main aspects which shall be considered during projects based on oil tankers conversion into FPSOs, emphasizing the topics that can influence the overall progress of the works.
Contractual requirements have been highlighted, such as minimum Brazilian national content, engineering scope of work, type of contracting, standardization of systems, construction using topside modules concept and some other points. Special attention must be given to the material and piping specification, as well as to the versions of applicable Rules and Regulations and Classification Society requirements. Case study based on the FPSO PETROBRAS 50 (P-50) and its " younger sister?? PETROBRAS 54 (P-54) project is presented, giving special attention to the Topsides and Marine systems, as well as to hull conversion works and related technical documentation. All the advantages obtained from the similarity and repeatability between the projects have been discussed, showing how they contributed to reduce the delivery time of the Unit.
Other aspects adopted in such projects will be presented herein, such as: integrated team between the Operation and C&A (Construction & Assembling). Also, a focus on HSE (Healthy, Safety and Environment) during the construction and assembling phase will be presented.

Introduction
The development plan of an oil production field starts during the conception phase. During this phase, the type of the Unit to be installed and the construction schedule are defined. If the Unit to be adopted is a FPSO (Floating, Production, Storage and Offloading), 02 (two) options are possible: a tanker conversion or a new built hull.
The type of Unit to be adopted for the field exploitation depends mainly on a technical-economic analysis, which is developed by PETROBRAS. At this moment, some alternatives are evaluated and considered, such as the type of hull (converted vessel into a FPSO, FPSO with new hull, converted Semi-Submersible, new SS), capacity of the production plant, facilities, etc. According to the economic-financial return for each option and taken into account the possibilities at the moment (availability of vessels for conversion, for instance), the chosen alternative will be the one that presents the best results.
In general, the technical teams prefer customized projects for production Units. It means that the Unit must be a " Taylor made?? project, built specifically for each field. However, in some situations, this is not the best alternative to be followed. In this way, the premises of repeatability and similarity are an optimized and very attractive decision that will result in a highest financial gain.
Effectiveness of Polyethylene Helical Strakes in Suppressing VIV Responses After Sustaining High Roller Load Deformation During S-lay Installation
Authors: Boubenider Rafik , Alptunaer Kaya , Fourchy Paul J. , de Wilde Jaap 
Published: October 2008

Abstract
Helical strakes are an important Vortex Induced Vibration (VIV) suppression device for Steel Catenary Risers (SCR's). This paper presents the results of two sets of hydrodynamic tests performed at MARIN, on a 12?? pipe fitted with 16D Helical Polyethylene strakes. The first set of tests established the suppression efficiency of the strakes for the Intact Configuration (no deformation). The second set of tests established the performance of the same strakes after undergoing a roller test in which the fins and the body of the strakes have sustained permanent deformations due to a simulated high contact load on the roller of a stinger during an S-lay installation. The type of permanent deformations sustained by the strakes can be described as bulging of the strake body, and permanent folding of the fins. Both configurations of the strakes (Intact and Deformed) were tested at high and low Reynolds numbers (velocities of 2.5 m/s and 0.5 m/s) and at different reduced velocities Vr. The results show that for the Deformed strakes configuration, there was no appreciable decrease in the VIV suppression efficiency of the strakes from a design consideration. The test results indicated that both Intact and Deformed strakes were at least 90% efficient in suppressing VIV. Therefore, based on the tests reported in this paper, the Polyethylene strakes were deemed acceptable to use on the SCR's even when using the S-Lay installation method.
Extending the Use of Conventional Construction Technology for the Installation of Subsea Production Facilities in Deep Water
Authors: Vennemann Olav , Frazer Ian , Tornqvist Rikard 
Published: October 2008

Abstract
It is clear that the offshore industry is striving to develop fields in deeper and deeper water and that subsea production is a key element in this development. This then leads to the question of what is the most efficient method of installing subsea production equipment in very deep water. This paper will address the issues associated with using conventional lifting technology based on steel wire rope for deep water applications. The new deep water construction ships being brought into operation have conventional lifting equipment based on steel wire rope. The requirement to be able to handle loads in excess of 300 t in great water depths leads to the need for large diameter multi-strand ropes with low spin characteristics. The long term behaviour of these ropes particularly in applications which require the use of heave compensator is uncertain due to the lack of any suitable test data. This paper will describe a full scale testing program to determine the fatigue performance of large diameter steel wire rope, including the design and building of a new testing machine, together with a summary of the results and the impact the results have on installation operations.

Background
On many of new deep water construction vessels coming into the industry, large wire ropes of 109 mm diameter are used for deepwater installation tasks and A&R activities. Some of these ropes are multi-strand ropes with low torque characteristics designed to be used in a single-fall arrangement. The ropes are subjected to bending when passing over a number of sheaves before overboarding the vessel. In many of the construction vessels, such as the Polar Queen (see Figure 1), an additional Heave Compensator (HC) is included into the deepwater installation system. This will potentially increase the number of bend cycles of the rope significantly depending on the duration of the use of the HC.
A literature research indicated that very little data is available on bending fatigue performance of large diameter ropes under load. Several sources were found presenting bending fatigue results of smaller diameters (Gibson 1980, Potts & Chaplin 1990, Müller 1961) but very little experience was documented on ropes over 90mm diameter. Further investigations showed that no such test facility was available to perform bending fatigue tests on large diameter ropes of 109 mm.
Based on these findings, it was decided to build a test rig to perform cyclic bending fatigue tests which would simulate the severe conditions experienced by the rope when used for subsea handling tasks and to perform cycling bending fatigue tests. These tests were accompanied by NDT tests to document the rope deterioration during the bending fatigue performance.
Feasibility Assessment of a Mid-Water Transfer System
Authors: de Abreu Alvim Roberto , Elman Priscilla 
Published: October 2008

Abstract
The development of deepwater oil fields based on a production platform with dry trees, connected to a Floating Production Storage and Offloading (FPSO) vessel, has proved to be technically and economically attractive. However, a key issue for the practical implementation of this production concept is the availability of a cost-effective oil and gas transfer riser solution.
The use of conventional catenary or self-standing riser technologies is sometimes avoided by operators due to high costs and flow assurance issues. To counter these problems operators are seeking a cost-effective solution for fluid transportation between two vessels at a water depth close to the surface. This type of riser system has been used successfully in benign environments like West Africa and is now being considered for harsher environments such as offshore Brazil.
2H Offshore conducted a preliminary feasibility study encompassing installation and in-service dynamic response, to prove the technical feasibility of a system composed of a group of large diameter free-hanging flexible pipes, required to connect two platforms offshore Brazil.
The paper demonstrates that this configuration is practical and simple because it can be designed with regular flexible pipe and standard components. Additionally, it can be deployed using conventional flexible pipe laying vessels.

Introduction
The design of a riser solution to connect a spread moored Floating Production Storage and Offloading vessel with a dry completion platform (Tensioned Leg Wellhead Platform - TLWP) is a complex engineering process which is being sought by operators as a novel and cost effective solution for fluid transportation.
The objective is to transfer the produced oil from the TLWP to the FPSO for processing, storage and later off-loading to a shuttle vessel. Additionally water is injected from the FPSO back to the TLWP and into the wells. This type of system has been proposed by several companies and is referred to as a " Mid-Water Transfer System??, hereinafter referred to as MWTS.
Due to the increasing demand for riser solutions in deep water developments, the use of conventional catenary risers (Flexible/SCRs) or Free Standing Hybrid Riser (FSHR) technologies, are sometimes avoided due to their cost. This paper evaluates a novel and cost effective solution for fluid transportation between the two rigs, considering flexible risers which are suspended close to the water surface. This allows the use of cheaper flexible risers with low collapse pressure limits which, reduces the cost of the riser system.
2H Offshore has conducted a preliminary feasibility study to prove the technical feasibility of a system composed of a group of large diameter free-hanging flexible pipes required to connect two platforms in offshore Brazil. The study covers the installation, in-service dynamic response and slugging behaviour of the system.
Structural Design Overview of the Drill Ships
Authors: Lim Yu Chang , Moon Hae Am , Kim Jin Tae , Kim Jong Ku 
Published: October 2008

Abstract
Daewoo Shipbuilding and Marine Engineering (DSME) was awarded the contract to build four drillships capable of drilling up to 30,000 feet in 10,000 feet water depth and scheduled for delivery by mid September 2008. The structural design of the drillships was based on the operating experience of the owner Transocean Offshore Deepwater Drilling Inc, and takes into account the new requirements of DnV OS Rules and CSA2 guidelines.
The former are based on Load and Resistance Factor (LRFD) format, which is different from the other conventional approach, Working Stress Design (WSD). Whole ship analysis was performed. The overall structural design procedures for the drillships are presented and recommendations are proposed in the paper. Other features of the structural design process including the fatigue assessment and accidental load assessments are presented.

Structural Design Basis.
According to COMPANY and Class requirements, the following design concepts for the Hull structural strength evaluation was considered.

1A1
This is the main class requirement with which all ocean going vessel should comply. The details of the requirement are specified in Ship Vessel Rule.
The main class requirements met through local scantling by ‘DNV/Nauticus Hull' and hold FE analysis based on Classification Notes 31.3 Strength Analysis of Hull Structures in Tankers

OS-C102
DNV OS-C102 specifies that offshore ships are to be designed to comply with LRFD design concept as defined in OS-C101 as well as main class requirements. It is to be noted, however, that the severity of onsite environmental loadings determined whether to apply the LRFD design concept. The subject vessel was assumed to be operating in relatively harsh environment for which the LRFD was mandatory to be applied. The subsequent chapters was prepared on this assumption.
The requirement specified three limit states in its details:ULS (Ultimate Limit State)FLS (Fatigue Limit State)ALS (Accidental Limit State)
The capacity assessment in the ULS condition included buckling and yield checks. Gross scantlings were utilized in the calculation of the buckling capacity of the hull structural elements. The strength of the hull girder was assessed based on the load conditions that result in maximum longitudinal tension and compression stresses in deck and bottom plating. The strength of the supporting structure for the topside facilities was evaluated considering relevant operational load conditions and their combinations. The local requirements for the structural members in the fore and aft ship including deck houses and accommodation were designed to comply with the technical requirements given in the Rules for Classification of Ships Pt.3 Ch.1.
Lightening the Load (LNG)
Authors: Gilchrist Robert 
Published: October 2008

Introduction
There are a number of motivators driving LNG side-by-side as a cargo transfer option, not least the success of floating solu-tions in Oil and LPG production projects. The main problem faced is that present LNG ships are designed for conventional manifold loading only. This, coupled with the fact that suitable floating LNG hoses only being in the early stage of develop-ment, ensure that tandem loading is not an option at this time.
We also have the situation where it is increasingly difficult to build a shore terminal for receiving Bulk LNG. Ports big enough for the ships are increasingly congested and bulk LNG terminals have strict HSE requirements. The option of having Floating Storage and Regasification Units (FSRUs) situated offshore but near to the ports, offers a solution that is being ex-plored by a number of importers. This again will require side-by-side for discharge, as the gas will increasingly come from the spot market on standard long-haul vessels.
With FPSO LNG projects now coming off the drawing boards and going into the yards, companies have to be certain of the capabilities of the Ship-to-Ship (STS) Industry. STS Service Providers need to use their experience to provide an operational envelope that makes the economics work.
Historically, Ship to Ship Transfers were generally considered something of a ‘risky’ operation, only carried out when abso-lutely necessary. There is now a growing confidence that the STS Industry today can deliver a high quality, repeatable opera-tion and meet the high safety standards expected in the LNG Industry.
The StatoilHydro IOR Program
Authors: Jorgenvag Astrid H. , Sagli Jan Richard 
Published: October 2008

Abstract
The paper includes:A brief introduction to the main technologies being developed and implemented in StatoilHydro's IOR R&D program.An evaluation of how the technologies will influence on the recovery from the company's existing fields
StatoilHydro will give a brief introduction to how the company envisages fulfilling the demanding requirements to significantly improve the oil recovery from producing fields. StatoilHydro's recoveries are favourably compared to other operators. The paper will put the presented technologies and methods into the IOR perspective.
StatoilHydro has traditionally had its focus on the Norwegian Continental Shelf (NCS). The focus is now turning towards deeper waters like the Gulf of Mexico, and arctic areas. This means that it is crucial that technologies that are being developed should be suited also for these fields.

Introduction
As a mean to meet the StatoilHydro business challenge of " Increasing the value of existing business and secure platform for further growth??, the Improved Oil Recovery (IOR) research programme was established after the merger of Statoil and Hydro Oil & Gas in October 2007. Based on the subsurface activities from the former Statoil research programmes SIOR and TAIL, together with Hydro's IOR programme, a large and powerful R&D programme, including geophysics, reservoir, drilling, well and production technology was formed.
The IOR programme was established to supply StatoilHydro's assets with critical technology and work processes in order to achieve a world class recovery factor from all relevant areas. A good collaboration model with the relevant business area in the company has been established.
The StatoilHydro assets on the NCS are in a situation where new technology is required " today?? to maintain the production level. This applies in particular to the mature fields like Heidrun, Gullfaks, Snorre, Brage and Oseberg. The somewhat younger subsea fields will within a few years be in a similar situation. It is of high importance to develop the technology needed in due time to make use of the existing infrastructure.
StatoilHydro has a high focus on the Gulf of Mexico (GoM), where deep water technology will be essential. StatoilHydro does not have any leading position in deep waters today and new technologies both within solutions for field development as well as for reservoir management will be crucial to achieve a sound economic result of the investments. Most of the efforts on shallow waters will be directly relevant also for deep water applications. The increased focus on carbonate reservoirs from the portfolio outside the NCS requires new competence and technology.