bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Flow Assurance Assessment Of Possible Low Temperature Excursions Within A Flowline/Pipeline System
Authors: Mcdermott Chris , Dewalt Brad 
Published: October 2011

Abstract
During the course of a flow assurance analysis of most deepwater field developments, low temperature excursions within the flowline/pipeline system is an area of concern that sometimes receives too little attention or is frequently not considered early enough in the design process. If this issue is not adequately addressed, it may limit the operational flexibility of the development, compromise material selection or certification and result in potential operational hazards being overlooked.
This paper will attempt to address these concerns while discussing the following aspects of this important design issue:–Description of operational scenarios where low temperature excursions are likely to occur.–Considerations in selecting applicable design cases while cautioning against selection of design cases that result in overly restrictive design criteria.–Review of relevant design guidelines and codes currently applicable to low temperature design issues.–Overview of design procedures for effectively evaluating low temperature excursions.–Modeling considerations when evaluating low temperature excursions using a variety of simulation tools.–The possible impact on project interfaces and the resulting effects on project schedule and challenges to equipment certification.–Overview of remedial measures if low temperature excursions present operational problems.
In addition, this paper will include two design examples:–Low temperature on start up across a subsea choke valve.–Low temperature excursion due to rapid depressurization of a small pipeline volume, e.g. riser only blowdown.
These design examples will be used to examine the issues stated above while providing a useful heuristic to assess any low temperature design issues within a flowline/pipeline system.

Introduction
The focus of this paper will be on low temperature excursions that occur within the subsea domain of an offshore system. This paper will not consider the low temperatures experienced in a topside flare system downstream of a blowdown valve, which is often a valid concern but is typically examined in detail during the topsides design.
The two main scenarios that the paper will consider are:Low temperature across a subsea choke during the cold restart of a well: If the system downstream of the choke has been depressurized to a low pressure prior to restarting the well, there will be a large differential pressure across the valve due to potentially high shut in tubing pressures. If the tubing is filled with a gas column, very low temperatures can be experienced downstream of the subsea choke due to Joule Thomson cooling during restart. The magnitude of the temperature drop will be impacted by the fluid composition and the initial pressure differential.Blowdown of a gas filled riser: When a small volume of gas is depressurized, the gas will undergo a rapid expansion, which can result in low temperatures upstream of a topsides blowdown valve.
Feedback from Experience on Structural Integrity of Floating Offshore Installations
Authors: Biasotto Paulo , Rouhan Antoine 
Published: October 2011

Abstract
Industry has experienced a significant increasing on the number of floating systems in the recent years. Current order book and potential projects under study indicate also that this number might increase even more significantly along the next 10 years. At some point in their lives, these facilities will present ageing signs such as corrosion, buckling and fatigue.
The paper provides feedback from experience on structural integrity assessment of production and drilling units and presents significative technical aspects identified along several projects. Failure mechanisms such as corrosion, fatigue and buckling are discussed, as well the techniques to analysis and assess structural integrity, remediations to address anomalies and defects, inspection planning and execution.
The use of adequate techniques and new technologies are important parameters in the overall integrity management process, but there might not be a single right way or process to ensure structural integrity, thus consensus may not be always achieved. Nevertheless, a successful implementation and continuation of Structural Integrity Management programs is strongly dependent on operators understanding of risks and potential consequences, in such way that integrity managers and staff involved in integrity activities are committed with such programs and they are well understood by stakeholders and across different organizations.
The paper will highlight best practices and procedures applied to structural integrity management of floating offshore installations, including not only technical aspects, but also integrity management review process, data and communication management.
The Role of Autonomous Underwater Vehicles in Deepwater Life of Field Integrity Management
Authors: Mcleod Daniel , Jacobson John R. 
Published: October 2011

Abstract
Integrity Management of deepwater fields requires routine general visual inspections of critical infrastructure. To date the only means of conducting general visual inspection is through the use of ROVs. Deepwater ROV spreads are large and heavy requiring large support vessels with dynamic positioning capability and a significant number of personnel at sea.
The capabilities of unmanned underwater vehicles have been enhanced through developments in Autonomous technology progressing to the point that autonomous underwater vehicles can now routinely conduct general visual inspection of subsea facilities. Benefits of Autonomous inspection include:–Reduced cost of operations–Faster inspection–Automatic Change Detection–Georegistered inspection data–Simultaneous operations from a single support vessel–Large standoff distances from the facility being inspected–Increased safety of operations–Reduced environmental impact–Reduced specification requirements on support vessel○Smaller footprint○Dynamic Positioning not required
Planning And Placing First Waimea Horizontal Production Well - A Case History - Campos Basin, Brazil
Authors: Flores Sergio , Rafainer Gilberto , Ernesto Paulo , Rosa Marcia R. Da S. , Costa Vagner , Ribeiro Mauro Torres , Landinez Giovanni , D&apos;Oliveira Diogo Scarcelli , Guedes Ana Beatriz Felicio , Ramirez Julian 
Published: October 2011

Abstract
The exploration campaign that started with the creation of the new company, in 2007, took another step forward with the drilling and completion of it's first horizontal producing well in the Campos Basin. The Waimea accumulation was discovered in the third exploratory well drilled in December 2009 (1-OGX-3-RJS), and confirmed with formation tests. The main reservoir drilled in well 1-OGX-3-RJS contained high energy carbonates intercalated with shales, occurring in structural and stratigraphic traps limited by normal and compressive geological failures in the NE-SW direction.
To ensure the commercial production of this accumulation, the development plan will require the drilling of several horizontal wells with high productivity index. This paper explains how careful planning along with well placement technologies were used to mitigate the geological uncertainties involved in drilling a horizontal well in a carbonate reservoir. The result was a successful production well at an early stage in the exploratory campaign.
Some of the key design and operation aspects which contributed to the success of the well were:–The initial design objective for the Waimea Extension well was to define a directional well profile and a linked horizontal profile such that both intersected at the planned entry point of the horizontal section, this challenging approach was key to obtaining further knowledge of these highly fractured carbonate reservoirs.–The evaluation of several alternative trajectories with the seismic data and, proper petrophysical properties analysis from the pilot hole log data to maximize well bore contact with the reservoir, to achieve the highest possible net pay in 1000 meters of horizontal geosteering.–The development of a geomechanical study to review these trajectories and define mud weight windows for safe drilling with minimum fluid invasion.–The use of well placement technologies with the support of, fit for purpose, rotary steerable system with logging while drilling tools which provided vital real time formation evaluation data for geosteering.
The planning and execution of the well culminated in excelent results for this first horizontal producer, with high net pay over the 1000 meters drilled and well testing confirming the well's high production potencial.
Mooring System Integrity: Deteriorative Mechanisms on Mooring Systems and Appropriate Inspection Techniques
Authors: Hall Anthony David , Trower Alastair Michael 
Published: October 2011

Abstract
The mean time to failure of most permanently installed FPSO mooring systems is 7.6 years, in spite of design lives of 3 times that. This paper will combine an introduction to, and identification of, mechanisms that are deemed unique to floating production systems. For the purpose of this paper these have been classified into two categories:

Mechanical Deteriorative Mechanisms;
– Sea floor trenching – Chain Wear – Turret Hawser Tube/Bending Shoe/Fairlead Issues – Out of Plane Bending – Differential loading – Fairlead/chain run-out – Vortex Induced vibration

Biological Deteriorative Mechanisms;
– Sulphur Reducing Bacteria (SRB) in the water column, hawser tube and in sea-floor material. Identification of SRB related pitting that can lead to crack propagation within individual chain links – Microbially Induced Corrosion caused by specific interactions between sea floor mooring system and water temperature

The presentation will include:
– An examination of deteriorative mechanisms using photographic, graphic and video evidence. – A brief overview of the classification and legislative requirements for permanent floating production mooring systems – An overview of the measurement and inspection techniques available in the industry – An overview of industry best practice guidelines for Mooring Integrity Management
Improved Girth Welds Manufacturing for Fatigue Demanding Deep Water Developments Through Laser Pipe End Measurement
Authors: Motta Lorenzo , Darcis Philippe , Novelli Paolo , Tintori Federico 
Published: October 2011

Abstract
Laser measurement systems (fixed and portable) have been developed by Tenaris to perform an automatic dimensional inspection of pipe ends.
Measuring OD, ID and WT, this tool is helpful not only for pipeline producers, which can have a better knowledge of the manufactured pipe ends' geometry, but also for the laying companies and for the end users, giving useful information in order to perform more efficient pipe line-up prior welding.
Since fatigue is normally the main limiting design criterion for fatigue sensitive products like flowlines and risers, representing a major engineering challenge, one way to minimize the risks of girth welds' fatigue failure is to reduce the pipes abutting Hi-Lo. This task could be accomplished by the use of laser pipe ends measurements analyses together with dedicated software.
Improvement of line-up pipe is very important for offshore oil recovery industry, where the fatigue requirements of pipelines subject to high dynamic loads are continuously increasing, as the exploitation is moving in harsh environments.
This paper describes the validation process and the implementation of automatic measurement systems for the inspection of the pipe ends' dimensions with high repeatability and precision. In addition, the following software applications are showed:–Division in families: determination of pipes groups according to their OD/ID/WT tolerances;–Best Matching: search of the alignments which minimize pipes abutting Hi-Lo;–Counter-Boring: analysis of the best pipe ends ID and/or OD to be machined and of the residual WT forecast after counter-boring.

Introduction
The increasing requirements of risers and flowlines subject to fatigue loads are leading to an interest of pipe ends laser measurements, aiming to enhance girth weld manufacturing and consequently their fatigue strength.
Fatigue is becoming one of the most important aspects to be taken into account in the design of offshore floating production systems (e.g. Spar, Semi-submersible, Tension Leg Platform (TLP), Floating Production Storage and Offloading (FPSO)). Due to their highly compliant nature, fatigue loading is accentuated particularly if compared to traditional fixed-bottom platforms. Fatigue loading arises due to production systems' motions that are caused by current action and waves. Some of the most fatigue critical components of these systems are the import and export Steel Catenary Risers (SCRs). Wave motions transmit significant fatigue loading to SCR, in particular at the touchdown location where the nearly vertical riser curves to join the pipeline or flowline on the ocean floor. In addition, the riser can experience fatigue loading due to vibrations induced by sea currents, like Vortex Induced Vibrations (VIV). These vibrations can occur at any number of locations along the riser length depending on the dynamic response of the structure and the current profile.
New Solutions for Subsea Produced Water Separation and Treatment in Deepwater
Authors: Anres Stephane Jean , Butin Nicolas , Evans Wayne , Bigeonneau Didier 
Published: October 2011

Abstract
Subsea processing is becoming necessary for subsea production enhancement in deepwater. For brown fields, when water production is increasing, subsea oil/water separation with water re-injection into the reservoir is a relevant solution. When operated subsea, the produced water treatment will increase oil recovery from mature fields and generate spare topside capacity in order to tie back new wells. Indeed, this solution will provide process capacity for oil (reduction of total liquids) and capacity for injection water (reduction of seawater needs).
Current oil/water separation units (Troll and Tordis operated both by Statoil in North Sea) are installed in relatively shallow waters and re-inject produced water into disposal wells. For deepwater applications, the large diameter vessels used on these two projects are not practical, due to the very thick wall required to sustain high pressure (either hydrostatic pressure or wellhead shut in pressure). Saipem is currently developing two bulk liquid separation systems to fit deepwater requirements, one based on gravity separation using several pipes working in parallel, and the second one based on cyclonic separation with compact equipment.
After this first separation stage, if produced water is re-injected into injection wells, additional water treatment is then required to meet the stringent requirements of oil-in-water and solids-in-water contents.
On this basis, Saipem and Veolia Water have partnered together to develop a series of solutions for deep water produced water treatment, targeting a water quality compliant with operators' requirements to inject produced water safely in existing or new injection wells. One of the developed solutions is based on the use of ceramic membranes which bring advantages compared to more conventional cyclonic systems, giving a much better water quality.
This paper will present the global solutions developed for deepwater applications, from the first separation stage to the produced water treatment stage, giving the expected performances and the current maturity of the whole system.

Introduction
The production of a large number of deepwater fields requires water injection in order to sweep the oil to the production wells (water flooding) and/or to maintain the reservoir pressure by replacing the volume of the produced fluids.
The injected water has conventionally been treated seawater while the water coming from the production stream is separated on topsides and disposed to the sea. As produced water cuts increase, produced water reinjection has become common, the oily water being treated on the topsides prior to injection.
This paper addresses Subsea Produced Water Re-Injection (SPWRI) applied to mature deepwater fields producing a large amount of water. It consists of separating most of the produced water on the seabed and reinjecting it into the reservoir through water injection wells.
What If Scenario Testing of Synthetic Fibre Rope for Deepwater Mooring Systems
Authors: Rowley David Stuart , Leite Sergio 
Published: October 2011

Abstract
Given industry concerns about the rising cost of performing deepwater installations, Lankhorst Ropes Offshore Division has developed a rope test machine that is expected to provide insights into deepwater mooring rope behaviour and optimise installation scenarios. For example, more accurate information on the degree of pre-loading required will avoid the high cost and safety issues surrounding excessive pre-loading during offshore installation.
Naval architects need comprehensive fibre rope test data when designing rope mooring systems. The rope test machine will provide the opportunity to conduct extensive testing of stiffness and degree of stretch under maximum load for a range of rope constructions, together with 'what if' scenarios by simulating storms and hurricanes, and loop current events with associated vortex induced vibrations on the mooring lines.
Using the rope test results, a new approach to pre-tensioning ropes ahead of installation is described. The approach is designed to address the issue of installing ropes of increasing stiffness and their associated higher mooring installation costs. In so doing it is intended to equip naval architects with a greater understanding of the performance of different synthetic yarns and rope constructions when designing deepwater mooring systems, and the role of pre-tensioning during installation.
Lessons Learned From Statfjord A Oil Spill and Actions Taken to Reduce Spill Risk During Offloading Operations
Authors: Meling Trond Stokka , Heen Per 
Published: October 2011

Abstract
December 12, 2007, several incidents and miscommunication during an offloading operation from the GBS Statfjord A to a shuttle tanker led to a 4400 m3 large oil spill.
The paper will present what caused the oil spill and lessons learned. The main focus in the paper will be on actions taken to reduce the risk for future oil spills during offloading including harware upgrade, monitoring, improved offloading procedures and inspection and maintenance programs.
A central element is the FMEA test program that was developed to ensure that the entire cargo line on the shuttle tankers was working as intended in the design philosophy. All shuttle tankers used by Statoil in the North Sea has now gone through the FMEA test program and an extensive upgrade program was required to meet the design requirements. Statoil believe the risk of oil spills during our offloading operations is significantly reduced after this work program was carried out.
The lessons learned from this incident is relevant for all offloading operations, and the actions taken to reduce spill risk can also be adopted by other operators in their offloading operations

Nomenclature
APL Advanced Production and Loading
BLS Bow loading System
FMEA Failure Mode and Effect Analysis
GBS Gravity Based Structure
OLS Offshore Loading System
PSA Petroleum Safety Authorities (in Norway)

Background
The Statfjord field is one of the oldest and largest oil fields in the North Sea. It is developed with 3 large Gravity Based Structures (GBS), see Figure 1, and production started from Statfjord A in 1979. The maximum daily production was 850 000 bbls in 1987, and the crude oil was originally exported through 3 articulated loading towers located 2-3 km from the platforms. The water depth at Statfjord is around 150 m.
Enhancing Local Content for Projects
Authors: Bonnel Pierre-Olivier 
Published: October 2011

Abstract
BR Petrobras plans to spend $224 billion through 2014 to develop deepsea oil finds. Supplying equipment in a timely fashion will be key to its efforts to nearly double oil production in Brazil by 2020. Brazil's government wants the majority of the cash headed to local companies or local units of foreign multinationals and wants to develop the oil services sector, creating industry that could export goods and services around the world. Thus, gradually, the minimum local content requirements will increase up to 95% in 2017.
Whoever wishes to have a major role in the E&P will have to establish significant local presence, in particular equipment suppliers (topsides, pipes, drilling packages, power packages for offshore units, etc.), who will likely need to build production facilities in Brazil.
The issue is not only to install local manufacturing support, but also pre-sales technical support, a presence close to the shipyards and operators throughout the phase of integration, commissioning and operation, and a very strong and effective after-sale support.
The paper will discuss the overall strategy needed to bring to Brazil the technical and manufacturing expertise to support the rapid growth of the shipbuilding industry and will examine the importance of providing local support to the yards and owners to reduce delays in technical proposal and during the construction phase of vessels.
Honeywell has set up, in addition of its already existing operations, a Marine operation in Rio de Janeiro. This unit includes:Front End Engineering Desing (FEED)Customer Engineering Project SupportTechnical sales supportInstallation & Commissioning support.Service StationLocal spare part inventory.
Consideration will also be given to a study being run by Honeywell to implement an assembly line in Brazil to minimize logistics costs and delivery times.
Complement-Fixing Anti-Type VII Collagen Antibodies Are Induced in Th1-Polarized Lymph Nodes of Epidermolysis Bullosa Acquisita-Susceptible Mice
Authors: Hammers Christoph M. , Bieber Katja , Kalies Kathrin , Banczyk David , Ellebrecht Christoph T. , Ibrahim Saleh M. , Zillikens Detlef , Ludwig Ralf J. , Westermann Jürgen 
Published: October 2011

Abstract
The environment encountered in secondary lymphoid organs (e.g., lymph nodes) influences the outcome of immune responses. Immunization of mice with type VII collagen, an adhesion protein expressed at the cutaneous basement membrane, induces experimental epidermolysis bullosa acquisita (EBA). In this model, clinical disease is associated with the H2s haplotype of the MHC found in SJL/J mice. Most other strains (e.g., BALB/c, C57BL/6, NZM2410/J) are resistant to clinical disease, despite autoantibody production. Comparison of autoantibody response in EBA-resistant and -susceptible mice showed an IgG2-dominated response in the latter. We hypothesized that EBA susceptibility is due to specific cytokine gene expression in draining lymph nodes (dLN). To challenge this hypothesis, EBA-susceptible (SJL/J) and -resistant (BALB/c, C57BL/6) mice were immunized with type VII collagen, followed by analysis of clinical phenotype, subclasses of circulating and tissue-bound autoantibodies, complement activation, and cytokine gene expression in dLN. Disease manifestation was associated with induction of complement-fixing autoantibodies, confirming previous observations. Furthermore, however, IFN-γ/IL-4 ratio in dLN of EBA-susceptible mice was significantly increased compared with EBA-resistant strains, suggesting a Th1 polarization. Immunization of H2s-congenic C57BL/6 mice (B6.SJL-H2s) led to Th1 polarization in dLN and clinical disease. In addition to their cytokine milieu, EBA-susceptible and -resistant mice also differed regarding the expression of FcγR on peripheral leukocytes, in which a higher FcγRIV expression in SJL/J and B6.SJL-H2s mice, compared with C57BL/6, was associated with skin lesions. In summary, blistering in experimental EBA is regulated by both adaptive (divergent class switch recombination due to polarized cytokine expression) and innate (FcγR expression) immune mechanisms.