bluuebunny/crossref_metadata_2025 huggingface dataset:
Organizational Learning by 'Segmented Networks'
Authors: Choudhary Bishwajit
Published: May 2011

Researchers have long argued that a “right” degree of closeness among team members is necessary for innovation. At unhealthy extremes, while closeness leads to cloning and copycat attitude, increased distance can result in incompatibility and dissonance. Hence, actually building teams that possess “creative-tension” is easier said than done. This chapter develops specific factors that conceptualize an “optimum” distance (vis-à-vis closeness) in teams and later extends the factors to argue for a novel organizational form, the “segmented network.”
Client/Server and the Knowledge Directory
Authors: Galup Stuart D. , Dattero Ronald
Published: May 2011

Developing and supporting knowledge management systems that seamlessly integrate with the existing information technology infrastructure is a major challenge. This development requires the functionality to locate and disseminate knowledge. An integral part of this requirement is the knowledge directory - a layered component accessible by any knowledge requester that can direct the knowledge requester to the location of the knowledge, in whichever format it may exist. This chapter discusses a client/server architecture that employs the knowledge directory to support the development and ongoing maintenance of knowledge management systems.
Key Issues in IS Management in Norway
Authors: Gottschalk Petter
Published: May 2011

Information systems (IS) departments face many challenges in today’s rapidly changing environment. One approach to understanding these challenges is to survey IS managers to elicit what they consider are key issues. Studies of key IS management issues have been conducted for some years in many nations and regions. However, most of these surveys lack a theoretical basis for the selection of key issues. Furthermore, most studies have used a single-round or a multi-round Delphi method. This chapter provides an overview of research approaches to key issues studies combined with key issues results from previous research. The chapter presents methodological issues and choices for a survey on key issues in IS management which was conducted in Norway. A three step procedure for key issues selection is introduced, and a Q-sort analysis is adopted. The chapter presents results from the Q-sort survey and analysis. The highest ranked key issue in Norway, according to the survey, is concerned with improving links between information systems strategy and business strategy.
Designing and Implementing an IT Evaluation Program
Authors: van der Zee Han T.M.
Published: May 2011

When you can measure what you are speaking about, and express it in numbers, you know something about it; but when you cannot measure it, when you cannot express it in numbers, your knowledge is of a meager and unsatisfactory kind; it may be the beginning of knowledge, but you have scarcely in your thoughts advanced to the stage of science.1
Towards a Model for Architectural Coordination of Business and IT Perspective
Authors: Enquist Hakan , Magoulas Thanos
Published: May 2011

Development of information systems in complex and dynamic organisations has failed in many aspects often due to the inability to manage complexity in interdependent enterprise and information systems changes. This paper presents some essential difficulties from the case project in systems development based on IT products like ERP products. We give an example of critical architectural issues where our understanding must increase to make a powerful management tool in business/enterprise and IT development. A conceptual model of actors and relations to support coordination of architecture from business perspective and IT supplier perspective is outlined.
Handling Structural Heterogeneity in OLAP
Authors: Hurtado Carlos A. , Gutierrez Claudio
Published: May 2011

Structural heterogeneous OLAP data arise when several OLAP dimensions with different structure are mixed into a single OLAP dimension. In this chapter, we examine the problems encountered when handling structurally heterogeneity in OLAP and survey techniques that have been proposed to solve them. We show how to incorporate structural heterogeneity in the design of OLAP models. We explain why structural heterogeneity weakens aggregate navigation, the framework that guides users to formulate correct OLAP operations and systems to efficiently process them. We survey different techniques to deal with heterogeneity, including the modeling of heterogeneity by unbalanced dimensions, the solution proposed by Kimball, and the use of null elements to fix heterogeneity. Finally, we present a class of integrity constraints to model structural heterogeneity, called dimension constraints, introduced in previous work of the authors. We show the practical application of dimension constraints to support aggregate navigation and some of the aforementioned techniques for dealing with the problem.
OLAP with a Database Cluster
Authors: Rohm Uwe
Published: May 2011

This chapter presents a new approach to on-line decision support systems that is scalable, fast, and capable of analysing even up-to-date data. It is based on a database cluster: a cluster of commercial off-the-shelf computers as hardware infrastructure and off-the-shelf database management systems as transactional storage managers. We focus on central architectural issues and on the performance implications of such a cluster-based decision support system. In the first half, we present a scalable infrastructure and discuss physical data design alternatives for cluster-based on-line decision support systems. In the second half of the chapter, we discuss query routing algorithms and freshness-aware scheduling. This protocol enables users to seamlessly decide how fresh the data analysed should be by allowing for different degrees of freshness of the OLAP nodes. In particular it becomes then possible to trade freshness of data for query performance.
Development and Testing of a Non-interlocked Hoop Strength Layer for Unbonded Flexible Pipe
Authors: Kalman Mark Douglas , Yu Liang , Moosberg Duane , Johnson Don
Published: May 2011

Conventional flexible pipe for high pressure applications generally employs a high lay angle, interlocked steel hoop strength layer to prevent blow through of the internal pressure sheath through gaps between adjacent wraps. The interlocked hoop strength layer is referred to as "pressure armour" in ISO 13628-2/API 17J [1]. The interlocking is designed to prevent large gaps from opening between adjacent wraps. The internal pressure sheath must span the gap under the internal pressure loading, and meet the ISO 13628-2/API 17J requirement of no greater than 30% thickness reduction at the gap location with the interlocking wraps in the fully extended position. To simplify the design of the hoop strength layer so that composite materials can be employed, a means of controlling the gap and preventing internal pressure sheath blow through between non-interlocked rectangular cross section hoop strength layer helical wraps has been developed. The non-interlocked design comprises an anti-extrusion and gap control layer applied between the internal pressure sheath and hoop strength layer. This paper presents the design of this new layer, the requirements to qualify the layer, tests which were conducted to verify qualification, and a validated model based on the test results for use in design of unbonded flexible pipe employing non-interlocked composite hoop reinforcement. The advantages of a non-interlocked composite hoop strength layer in unbonded flexible pipe include lighter weight structures, reducing risk and cost for installation and operation, and corrosion resistance making it ideal for deepwater and ultra-deepwater applications.

Introduction

Unbonded Flexible Fiber Reinforced Pipe (FFRP®) is a new generation of flexible pipe designed for offshore oil and gas transportation. It is constructed from extruded polymer pressure barrier layers and fiberglass/epoxy reinforcement layers. The unique design of bonding multiple thin reinforcement tapes into reinforcement stacks with interlaminar adhesive allows the reinforcement material to work in both tension and compression.

Because of the high strength-to-weight ratio of the composite reinforcement material, FFRP is ideal for deepwater and ultra-deepwater service. Figure 1 provides an isometric view of the unbonded FFRP pipe structure. A brief functional description of each layer is provided in Table 1.
Two Years After First Oil Paraffin and Scale Flow Assurance Management - Lessons Learned
Authors: Wylde Jonathan James
Published: May 2011

This paper describes the evaluation of paraffin and scale risk management based on real production samples, and how this differed to the assumptions made during the basis of design.

The production facility has two unmanned tiebacks with a field total of just under 20 wells. For first oil the paraffin and scale management strategy, like most of the flow assurance strategy, was based on pre-production samples. Two years after first oil, almost all the wells were sampled - the first such exercise of it's kind - gathering large and representative chemical free crude oil and produced water.

Produced water samples were analyzed enabling a system-wide scale review for production wells, departing pipelines and major processing vessels and equipment. Some scale had already been observed in the process, in the hydrocyclones and heat exchangers, and this evaluation helped to highlight the other key risk areas and develop appropriate mitigation strategies - not based on pre-production data and samples. This aided the operator in instigating a more robust scale inhibitor injection strategy, in particular for the subsea in-field flow lines.

The areas identified as having a paraffin deposition risk in the field were the fluids arriving from the subsea tiebacks where the arrival temperatures were lower than the cloud points. Cold finger testing identified that greater than 60% inhibition efficacy was realized when 10 to 50 ppm of the incumbent wax inhibitor was used.

Details are given on some of the shortcomings in the chemical injection system, capturing the lessons learned in control of wax and scale inhibitor distribution through the subsea injection system. Information is given on how this was countered using the most efficient and cost effective chemical mitigation strategy. Practical advice is then offered on how to better interpret pre-production samples to better predict and design flow assurance strategies prior to first oil.

Introduction

The field is an oil and gas asset development located in the Gulf of Mexico in water between 85 to 190 feet deep. It produces oil and gas with associated condensate. The designed processing capacity of the facility is 100 MBOPD and 280 MMcf/d of gas. The produced oil has a gravity between 28° to 34° API, and is low in sulfur and acid. The design anticipated the wells to produce up to 20% BS&W in late field life. Based on laboratory results, asphaltene deposition was not expected to be a concern; however, the pre-production crude samples had over 6% paraffin with a cloud point as high as 82°F. The crude oil export specification is 0.5% BS&W, and a TVP of 11.0 psia.
An Integrated Approach to Selecting and Optimizing Demulsifier Chemical Injection Points using Shearing Energy Analysis: A Justification for Downhole Injection in High Pressured Well
Authors: Opawale Adekunle Olutayo , Osisanya Samuel Olusola , Dulu Appah , Otakoro Solomon Ejaeta
Published: May 2011

Chemical demulsifiers are routinely injected into the petroleum production system at several points to effectively resolve water-in-oil emulsion issues. Point of injection varies from downhole through wellhead and manifolds to stocktanks (Batch treatment). Selection of the best injection points during oilfield practices still remains a very challenging task for both operators and chemical vendors. Many researches have not been done on this subject matter, and hence remains the focus of this study.

In this paper, models to carefully analyze and study the relationship between shearing energy and pressure drops at various points in a production system is developed. It analyses the Shearing action as the reservoir fluid flows through formation pores, perforations, tubing, wellhead chokes and the surface flowline. This program determines the best injection points for demulsifier chemicals to ensure their adequate mixing, mobility and strong partitioning at the water-oil interfaces where their actions are needed. This novel approach applies to several well geometry and completions, ranging from open to cased wells. Developed models were tested and validated with real data from a known oilfield in Nigeria. Wellhead and downhole injection (through gas lift valves) appear to be one of the best practicable injection points selected by the program. This selection already considered the current conditions of the field and produced fluid and also the nature of demulsifier chemical in use, in terms of its residence time of action. Results obtained vary with changes in these factors as the reservoir becomes depleted and workover operations are performed.

This paper emphasises the impact of shearing energy and pressure drops on the effectiveness of demulsifier chemicals. Determination of appropriate injection points combats lots of operational and economical problems such as over-treating and re-emulsification. It reduces unnecessary high budgets for demulsifier chemicals as injection rates will be optimized. This paper also discusses the benefits that can be realized by breaking emulsions downhole, and contributes to the existing literature in the design and construction of production chemical injection program for a green field development. The authors anticipate that the new concept of shearing energy analysis presented in this paper would contribute more to improving the technology of chemical-demulsification.
Influencing and Shaping HSE Policy and Practice in Joint Ventures
Authors: Robertson Carl Alan , Tuan Dang Anh , Iversen Martin
Published: May 2011

Dedicated focus on Health, Safety and Environmental (HSE) issues is a pre-requisite to successful operations in the Upstream Oil & Gas industry. The welfare of people - employees, contractors and stakeholders - is paramount, while ensuring mechanical integrity and containment and safe operations are critical as well. These issues become more complex in the context of a Joint Venture (JV) or Joint Operating Company (JOC) structure, and may be further complicated when multiple nationalities and corporate cultures are introduced into the mix.

This paper describes the historical safety performance and strategies and actions implemented by the Cuu Long Joint Operating Company (CLJOC) to create a positive HSE culture. CLJOC's exposure data will be broken down into the three major areas: Direct-hire Staff (DS), Operations, Maintenance & Drilling (OM&D) Contractors and Project Management (PM) Contractors. The data will be presented in the context of the growth of the Joint Operating Company and the impact of the Influence Model on the JOC safety performance will be shown.

Changing Industry Trends

Recent trends, driven by resource access challenges, have favored the formation of JV or JOC structures in which National companies have a controlling position. Partners may be other State companies, major public companies or small entrepreneurial organizations. Well established major operators may be involved as minority or non-controlling participants in the JOC's, with their staff acting as mentors in positions of influence without formal authority.

The culture and structure of JV's and JOC's can differ greatly from the typical company as they may employ many nationalities from multiple cultures. Each culture may have a differing perception of risk, with some having a high tolerance and low awareness compared to those which have experienced a more sophisticated safety culture.

JOC's and JV's have independent identities in which participants have influence but no direct organizational control. Participants may have differing (and at times conflicting) priorities and the work and living environments can be a challenge. There is a strong need to maintain corporate governance and adhere to stringent HSE standards as each partner is responsible for the health and welfare of their dependents.

CLJOC Background

The Cuu Long Joint Operating Company was established on October 28, 1998 for the purpose of operating Block 15-1, offshore Vietnam. Co-venturers in Block 15-1 include PetroVietnam Exploration & Production Corp., Ltd., 50.00%, ConocoPhillips (UK) Cuu Long Ltd., 23.25%, Korea National Oil Corp., 14.25%, SK Energy Co. Ltd., 9.00% and Geopetrol Vietnam SA, 3.50%.

Block 15-1 is located at the north end of the Cuu Long basin, about 180km east-southeast of Ho Chi Minh City. Oil was discovered in October 2000 and production began in October 2003; there are now three fields producing on the block.
Introduction to Remotely Operated Vehicle Assisted Subsea Sampling
Authors: Mancini Christopher S. , Turnbull Joshua
Published: May 2011

This paper introduces the reasoning, methods, and technology behind using a Remotely Operated Vehicle (ROV) to obtain a sample of production fluids from offshore sub-sea installations. Subsea sampling in this context involves physically delivering equipment to sub-sea installations, connecting to said installations, obtaining a measure of the product in question, and returning said measure of fluid to the surface in a specified condition. Methods and technologies relating to the transport and laboratory analysis of the product once delivered to the surface are examined briefly, but not in great detail. An explanation of why the offshore oil and gas industry is increasingly interested in subsea sampling, and the value it brings to operating companies is presented.

What is Subsea Sampling?

Subsea Sampling is the act of retrieving a measure of production fluid from a subsea installation such as a production tree, manifold, or other junction for the purpose of testing and recording information about said fluid. The quantity and type of fluid that is retrieved depends on the information that is required from the sample. The information retrieved from samples includes but is not limited to chemical composition, pressure volume temperature (PvT) analysis, salinity, and density. The values obtained for the different attributes are used to calibrate subsea multiphase flow meters and manage reservoir production and intervention schedules. Obtaining samples from installations in deep water, 5000 feet or more necessitates the use of remote operated vehicles (ROVs) to carry and manipulate the sample gathering and transport equipment, or the use of down wire tooling packages. The focus of this paper is the former.

Why is Subsea Sampling Performed?

Offshore oil and gas producers perform, or plan to perform subsea sampling for two reasons. The first reason is to support the use of subsea multiphase flow meters. The second reason is gathering data to support reservoir management efforts.
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

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

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

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

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

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

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

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

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

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.
SCR Integrity Management Program using Field Data from a Monitoring System
Authors: Enuganti Prahlad , Shakkari Phani , Constantinides Yiannis , Chen Jen-hwa , Garaudy Jennifer
Published: May 2011

Over the past several years, the focus of the oil industry has shifted towards Integrity Management (IM) of offshore platforms. A typical IM program of an offshore platform covers subsea equipment, riser/flowline, processing facilities and topsides. However, the integrity of the riser system is especially critical due to its complex dynamic response and as failures have potential to cause significant impact on life and environment. As part of Chevron's IM efforts on their deepwater floating systems, Chevron has instrumented one of its deepwater GoM platform SCRs with motion and strain monitoring devices. A key objective of the SCR monitoring program is to ensure that the response of the production riser is within safe operating conditions and pre-emptively identify any potential threats to riser integrity.

To maximize the benefits of the SCR IM program, riser monitoring data is processed in conjunction with prevalent environmental, vessel and riser operating conditions. Typically a riser design process contains a standard set of requirements, based on environmental and vessel conditions, that need to be satisfied before the riser is deemed suitable for use. As part of the SCR IM program, additional factors unaccounted during riser design have been identified that have an impact on riser response. Hence the value of a riser monitoring program to account for the limitations of the riser design process and to confirm the overall integrity of the riser system is established.

This paper discusses the methodology used and provides a summary of key findings from the processing of field measurements. The importance of monitoring will be highlighted and recommendations to operators for future integrity management programs will be provided.
Refining the Roles of ROVs and AUVs in the Next Decade
Authors: Johnson Mark A.
Published: May 2011

DESCRIPTION OF THE MATERIAL

The industry would like to develop technologies for remotely operated vehicles, (ROV's) and autonomous underwater vehicles, (AUV's), that can reside and reliably operate for extended periods without the costs of intervention vessels. The forward time period is defined as the next 5 to 10 years and extended subsea operation period is defined as 1 year with maintenance and possible replacement.

APPLICATION

The objective is to identify ROV / AUV sub-systems and components that would need modification or new design/development such that a vehicle system can reliably operate in a cost effective way for these offshore assets:Limited intervention vessel availabilityLong distance offsetsDrilling Riser inspection and BOP guidanceAssets that may have ice cover.FPSO Inspections

It is assumed that a light-class work vehicle would be capable of:Video observation of subsea equipmentOver-riding rotary and linear valvesReplacing electrical flying leadsJetting away silt or debris for observation or replacement operationsLeak detection

ROV's appears to be the correct equipment for vertical access and tooling required tasks. AUV's are best suited for longh horizontal survey operations. Considerable standards and subsea infrastructure would have to be implemented to incorporate vehicles into intervention tasks.