bluuebunny/crossref_metadata_2025_split huggingface dataset:
Phoenix Subsea Field Development: Challenges, Lessons Learned and Successes
Authors: Sutherland Christopher Alan , Macklin James P. 
Published: May 2011

Introduction
The Phoenix Development project was sanctioned to rejuvenate wells and reservoirs historically associated with the Typhoon and Boris fields. These fields sit in approximately 2,000 feet of water in OCS blocks Green Canyon 236 & 237 (Typhoon), 238 (Little Burn), & 282 (Boris). Cumulative production of 50 million barrels of oil equivalent was produced through the Typhoon tension leg platform (" TLP??) from start-up in July 2001 through September 2005. Damage to the Typhoon TLP, sustained during Hurricane Rita, forced the field to be shut-in. Final production averaged 13,000 barrels equivalent per day from four historical completions. Two additional wells were finalizing rig activity to restore field production levels to peak rates of over 35,000 barrels equivalent per day. A full economic evaluation was performed to determine the feasibility of a redevelopment project. Key indicators included the state of the subsea infrastructure and debris, analysis of subsurface performance along with host facility options. The details within this paper will give background information into the evaluation through sanction, install activities on site and results from initial production through the Helix Producer 1 (" HP 1??) host facility. Ownership of the Phoenix Development project is Energy Resource Technology GOM (WI- 70%) and Sojitz Energy Venture, Inc. (WI- 30%).

Evaluation/ Project Sanction

Subsea Infrastructure and Debris
The original operators, Chevron and BHP, performed inspections during the early response phase to assess damage to the subsea infrastructure. Inspections using both direct ROV intervention, as wells as side scan sonar were used to observe the subsea trees, flow lines and export pipelines as well as map the seafloor debris field. The 10?? × 12?? oil export steel catenary riser (" SCR??) and 18?? × 20?? gas export SCR were severed from the TLP along with four flexible Typhoon flow lines, five umbilicals and the Boris bulk oil gathering line. No gross damage was observed at the wellhead or trees for the previously producing wells. No leakage was observed at any of the severed pipeline ends and though the subsea distribution unit for the Boris field was off location by some fifteen hundred feet, it was in good condition. The debris field was largely disassociated with the lay routes as the TLP exited the basin in a north westerly direction. With the exception of the remaining umbilical and pipeline damage the debris field was entirely confined to the GC 236 and GC 237 blocks.
Coating Technology Improves Project Predictability and Lowers Costs for FPSO Conversion Projects
Authors: Azevedo Joao 
Published: May 2011

ABSTRACT
The role protective coatings' play in the predicable and timely conversion of an FPSO conversion project is commonly overlooked. This is due in part to the low cost of the coating materials when compared to the overall project costs. In addition to improved predictability, new technology coatings can help lower the cost and speed projects completion. Failure to understand the importance of this role can impact both the project schedule and the durability of the protection, resulting in added costs and delays many times greater than the cost of the coating itself. This paper describes the main challenges being faced regarding coatings selection & application today, and presents a surface & humidity tolerant solvent-free epoxy technology incorporating a unique combination of features to address them: reduced solvent emission, surface tolerance, application without humidity restrictions, edge-retention and compatibility with water jetting as a replacement to abrasive blasting. The description is based on both laboratory and field data.
This paper will help owners and shipyards identify traps posed by underestimating the impact of the blasting & painting activities in a FPSO conversion project. It also suggests an alternative concept, using water instead of abrasive for surface preparation and a novel tolerant coating system that copes with it, arguably with advantages for the project.
Data from successful laboratory prequalification tests, relevant performance testing and actual field application is presented. Observations are shared encompassing the application of over four-million square meters of steel in FPSO conversion projects. Significant field data is presented evidencing the efficiency of the application (time & costs savings) and the protection effectiveness (survey reports after years of service). The conclusion claims that this concept can improve schedules & completion predictability, environmental compliance, cost effectiveness and corrosion protection efficiency in such projects.
The concept presented changes, in a unique way, the traditional way of performing blasting & painting activities. This matter is being presented in the context of FPSO conversions for the first time and its significance arises also from the abundant data that is now possible to share as solid confirmation of the advantages claimed.

INTRODUCTION
The inability of owners and shipyards to accurately predict schedule and cost for FPSO conversions is the largest single factor affecting the conversion market today. The concepts presented in this paper have been documented to save 15% in coating system costs (surface preparation and application included) but, more importantly, allow for much improved scheduling for FPSO project completion time lines that can be greatly affected by coating application.
Offshore Gas Terminals - Guidance on Design and Construction
Authors: Fagan Conn 
Published: May 2011

Abstract
A number of floating offshore gas terminals are currently in development, a number of FSRUs have been installed and it is expected that the first LNG FPSOs will be entering detailed design phase and construction in the near future. Based on our experience within the gas industry and various conceptual assessments, DNV has produced a Guidance on key issues to be addressed in such projects. The Guidance addresses design issues, including selection of containment system, structural analysis of Floating Offshore LNG Terminal hulls as well as construction and testing issues.
The DNV Offshore Technical Guidance, OTG-02 " Floating Liquefied Gas Terminals??, an overview of which is presented in this paper, represents latest DNV and industry lessons on tackling design and construction issues for floating terminals.
This paper will only address a selected number of topics from the DNV Offshore Technical Guidance, namely:Background for the GuidanceStructural designSide by Side AnalysisArrangement and LayoutRisk Assessment issuesIntegrated control systemsInspection of Containment SystemsValidity of Codes and Regulations
The DNV Offshore Guidance itself additionally addresses issues such as :Conversion of gas shipsSloshing assessmentFatigue assessmentCorrosion issuesRegasification and liquefaction plantClassification and regulatory complianceAssessment of novel conceptsQualification of technology

Introduction
There are a number of options available for design of gas receiving and exporting terminals. Traditionally these have been built on land according to codes and standards, such as NFPA 59A, which have been specifically developed to address design and constructions issues of terminals to be built on relatively spacious sites but which may be in some proximity to the civil population on. These codes therefore include requirements and assumptions based on such arrangements.
Building such installations offshore, or close to shore, poses different challenges, for which at present, there is little relevant experience.
Solution to Design Challenges and Selections of Wind Turbine Installation Vessels
Authors: Lu Jenny Yan , Mony Santhosh Kumar , Carlsen Henning , Sixtensson Carl 
Published: May 2011

Abstract
Wind energy is one of the key renewable energy sources that will make a significant contribution towards the goals of clean energy around the world. The offshore wind energy industry is in a period of rapid growth, which results in a massive demand on the current supply chain. The large scale development demands specific installation and maintenance vessels.
Various wind turbine installation vessels are being designed or constructed with a combination of new and existing technologies. There are specific challenges and design considerations related to this kind of vessels. Understanding the critical design parameters and considerations for various design concepts of WTI units are important for proper selection of design and technical standards in order to ensure a safe and robust design. The industry needs new design standards developed with synergy from well established offshore/maritime practices to provide guidance for this new vessel type to meet the high energy demand and to ensure high safety standards in the offshore wind energy sector.
The paper first presents examples of various types of Wind Turbine Installation vessels that currently are being developed and then describe how DNV rules and standards address the specific challenges and critical elements for these various types of WTI units to ensure a safe and robust design. The paper then goes on to describes some of the key parameters and methodologies by which selection of these various design concepts can be carried out for a particular project/application.
Dredging for the Offshore Industry: Environmental Management Strategies
Authors: Van Der Goot Fokko , Nipius Karoune G. , Aarninkhof Stefan G. 
Published: May 2011

Abstract
Projects related to the offshore industry are often involved with the realization of complex infrastructures in sensitive marine environments. These projects show serious concerns about the preservation of environmental values, strong demands on assessment of impacts, strict controls on work methods and extensive monitoring programs during project realization. Generally, the contractor is responsible for minimizing the environmental impacts caused during project realization. Various impacts relate to dredging operations. This has readily inspired Royal Boskalis Westminster NV to develop a series of innovations aiming to mitigate the direct impact of dredging activities. Sustainable and cost-efficient realization of such projects can only be achieved on the basis of thorough understanding of dredging processes and their impact on the natural environment and state of the art environmental management and monitoring strategies.
Turbidity increase is the most common environmental effect of dredging operations. Boskalis has recently been involved in various projects (e.g. the construction of LNG terminals and pipeline-landfalls) that involved stringent limits to dredge-induced turbidity. By applying preparatory numerical environmental modeling, real-time monitoring control and implementing strict environmental management procedures Boskalis has proven to be able to control the impact of dredging works and realize complex projects in a sustainable and cost-efficient manner.
From these recent projects, various lessons were learned that helped to improve the management of environmental impact related to dredging works. These lessons are:Each project is unique. Restrictions and lessons learned at one project should be used with great care for the next project;Dredging-induced impacts should be evaluated for each project in relation to the surrounding ecosystem. Environmental restrictions should be based on the resilience of the local ecosystem, while accounting for natural fluctuations;Monitoring programs should be designed in an adaptive manner, to allow for review of the procedures and make adjustments if appropriate;Environmental monitoring should be integral part of project planning, to avoid unforeseen delays and costs.
Recent projects have demonstrated Boskalis' capability to successfully apply complex environmental monitoring strategies in present-day dredging practise. When communicated to the outside world, monitoring data were found to facilitate stakeholder involvement and public information purposes. In this way, environmental monitoring is of direct relevance for the success of marine infrastructure projects and their appreciation by the general public.
Debottlenecking of Mature Field Production through the Use of Very Compact and Efficient Separation Equipment, Topside or Subsea
Authors: Schook R. , Thierens Danny 
Published: May 2011

Abstract
In the past decade the use of very compact processing equipment, sometimes referred to as ‘Inline separation equipment’ has become more and more popular. In a number of cases, it has been possible to successfully de-bottleneck severely restricted process systems through the use of inline equipment. Successful examples on for instance Statoil platforms like those of Statfjord have been well documented.
However, compact separation technologies have not yet been able to gain general acceptance as standard building blocks for new process systems, or to take it one step further, have not yet been able make classical separation technologies obsolete.
The perceived operational disadvantages of inline equipment consist of it 1) being relative intolerant to variations in operating conditions (restricted turndown range) and 2) being complex equipment to design as no accurate, generic design rules exist. Moreover, most inline equipment is customized for a specific application.
This paper will highlight the development of a new generation of inline separation equipment. The new equipment is characterized by a much more efficient swirl generation. The principle of operation of most compact separation equipment is based on creating strong centrifugal forces that drive the separation of the well fluids. It is shown that the more efficient generation of this driving force creates much wider turn down ranges of critical operating conditions.
It is described how rigorous performance mapping has taken and still takes place under realistic operating conditions (both regarding scale and physical characteristics of test fluids) to prevent the design uncertainties that have sometimes hindered the correct application of these technologies today.
An example will be presented how these new inline components of which the performance characteristics are now well known can form an extremely compact process system with a pronounced tolerance against transient operating conditions (like slugging).
Decommissioning of Frigg and MCP01 - A Contractor View
Authors: Gram Torleif , Berger Jean-Claude , Kluge Rolf , Kristensen Jan Fredrik , Johannessen Morten , Krogh Espen , Hagemann C. 
Published: May 2011

Abstract
Frigg Cessation was the first major North Sea field decommissioning project. The project was a pioneering effort with a steep learning curve. The Frigg field platforms included both steel jackets and concrete gravity based structures with a total steel weight to be removed of about 87 000 tons. The paper deals with three aspects of the job seen from the contractor's point of view:The execution plan and methods developed prior to contract award.Unforeseen issues and consequent changes that had to be dealt with in order to execute the work.Lessons learned and key recommendations to operators and contractors alike.
The Frigg Cessation project was completed in 2010, two years before contractual completion date.

Scope of Work and Platform Overview
The scope of work consisted of management, engineering and procurement of all necessary labour and plant resources to prepare for.the safe removal and disposal of onshore, including the safe handling and disposal onshore of hazardous waste, six topsides and three jackets, in total about 87 000 tons of steel. The concrete structures were not part of the removal scheme and were left in place.
Upheaval Buckling Assessment Based on Pipeline Features
Authors: Thusyanthan Indrasenan , Mesmar Sultan , Robert Dilan , Wang Junkan , Haigh Stuart Kenneth 
Published: May 2011

Abstract
Upheaval buckling (UHB) is a common design issue for high temperature buried pipelines. This paper highlights some of the key issues affecting out-of-straightness (OOS) assessment of pipelines. The following factors are discussed; uplift resistance soil models, uplift resistance in cohesive soils, uplift mobilisation, ratcheting, uplift resistance at low H/D ratios and the correct methodology for load factor selection. A framework for determining ratcheting mobilisation is proposed. Further research is required to verify and validate this proposed framework. UHB assessment of three different diameter pipelines were carried out using finite element SAGE PROFILE package incorporating pipeline mobilisation and the results are compared with semi-analytical formulation proposed by Palmer et al. 1990. The paper also presents a summary of as-laid pipeline features based on projects over the past 10 years.

Introduction
Upheaval buckling (UHB) is a common design issue for buried pipelines when the out-of-straightness of the pipeline combined with the high axial compressive forces induced by the extreme operating conditions causes the pipeline to buckle upwards. In order to prevent upheaval buckling, the pipeline has to be buried deep enough such that the soil cover is sufficient to provide adequate uplift resistance. An out-of-straightness (OOS) assessment utilises the pipeline profile obtained from survey and appropriate soil modelling to calculate the soil or rock cover depths needed to mitigate UHB throughout the length of the pipeline. Figure 1(a) shows a typical schematic of upheaval buckling while Figure 1 (b) shows a pipeline in the field which has undergone upheaval buckling. Proper modeling of upheaval buckling requires in depth understanding of pipesoil interaction and key factors affecting buried pipeline behaviour. Uplift soil models, uplift resistance in cohesive soils, uplift mobilisation, ratcheting, uplift resistance at low H/D ratios and correct methodology for load factor selection for UHB assessment are all discussed in this paper.
During pipeline Front-End-Engineering-Design (FEED), the semi-analytical formulation proposed by Palmer et al. 1990 (OTC paper 6335) has been one of the fundamental methods of assessing the required uplift resistance for the last 20 years. The feature geometry being limited to prop-type and inability to account for the pipeline mobilisation during operation are often seen as a limitation of this formulation. This paper investigates these issues and provides the results to improve the understanding of UHB with mobiliation.
Review of Cabled Observatory Systems and Their Applications to Deep Water Oil and Gas
Authors: Woodroffe Adrian , Huster Andreas , White Derek Alan 
Published: May 2011

Abstract
Scientific cabled observatory systems have been deployed around the world with significantly increased capabilities over the last five years. The concept and rationale for cabled ocean observatories is introduced with detail on their function as modern and powerful tools used to understand a broad range of ocean science objectives. In addition to science, other applications are discussed, such as site and equipment monitoring for tidal and wave based renewable energy projects. Similarly, the same technology can be applied to oil and gas production (monitoring, control and intervention), along with port and coastal security surveillance. The paper provides an overview of cabled observatory elements with three cabled observatory projects described as examples. It describes the various features and capacities that each system offers to its users. The paper introduces a modular subsea uninterruptable power supply capable of providing 150kWhr of capacity per module. This system can be used in conjunction with cabled observatories to provide load leveling and guaranteed data collection in the event of a cable fault. The paper concludes with applications for cabled observatory systems related to environmental monitoring and well head control in the oil and gas industry.

SECTION 1 - CABLED OBSERVATORY OVERVIEW

I. INTRODUCTION
A cabled ocean observatory is a subsea infrastructure that can stretch for hundreds of kilometers along the ocean floor. Each observatory provides power and communications to arrays of distribution nodes located on the sea floor. The nodes are linked together with telecommunications cable that supplies electrical power and fiber optic communications.
Each node provides multiple connection points allowing a wide variety of sensors and other instruments to be interfaced to the system. Internet based communications allows data to be securely routed from each of the node to the user's facility. For the first time, scientists and engineers have access to real-time continuous data from the ocean, right to their office.
Cabled observatories are built from a number of modular building blocks, which are described in the following sections. As each application has different requirements, the cabled observatory modules can be arranged in different topologies, with different features. Figure 1 shows an overview of the key modules and an example of how these items may be connected together.

II. CABLE OBSERVATORY MODULES

A. Shore Station
Power and communications is often supplied to a cabled observatory from a purpose built shore station. The shore station provides the appropriate ocean access for the cable landing, power feed equipment (PFE) and media converters to link the subsea fiber to the Internet. A dedicated data back haul maybe required. An uninterruptable power supply (UPS) and data storage can also be included here to improve the system availability.
Diminishing Environmental Footprint & Costs in Offshore Produced Water Treatment
Authors: Parasarathy Harikrishnan 
Published: May 2011

Abstract
In an age of environmental concern and regulation, offshore technology is charged with meeting new operational challenges. To accomplish this broad goal for Oil and Gas Exploration & Production, engineers at MyCelx Technologies have worked with industry leaders worldwide to implement successful systems that treat the costly, environmental problem of produced water. MyCelx filtration media work using a chemical affinity for WSOs (Water Soluble Organic compounds problematic in produced water), rather than through basic mechanical action. In late 2010, the first application of this technology went online with a MyCelx-designed marine installation for Anadarko Petroleum in the Gulf of Mexico. The results surpassed the regulatory guidelines set by the EPA (29 parts per million) and accomplished the most stringent operational limit to date (10 parts per million). Current regulation is not reliably met by current alternatives, which also require much more space. The production platform safely discharges oil-free water safely into the environment and significantly reduces previous operational costs with a lighter, smaller, easy to maintain installation. This paper will support the financial, environmental, and relevant operational safety benefits of this new technology application. Supporting information includes results from laboratory and field work and a discussion of current regulatory standards and operational costs. In conclusion and in order to contribute to the knowledge base of the Offshore Drilling industry, the paper presents the benefit of chemical affinity in hydrocarbon filtration for regulatory compliance and improved environmental impact.