bluuebunny/crossref_metadata_2025_split huggingface dataset:
Buoyant Tower: Construction Challenges and Lessons Learned
Authors: Crochet Clyde , Toll Beau , Gommel John , Slider Mark 
Published: May 2013

Abstract
This paper presents a review of key steps and processes for the onshore construction and load-out of the world's first drilling and production buoyant tower; an alternative substructure to a piled jacket scope in a conventional execution. This paper also presents the onshore construction and load-out of the accompanying topside uniquely configured with a support frame serving as an offshore, cantilevered skidding frame used during float-over mating with the buoyant tower.
Key steps and processes in the construction were framed by the selection of the buoyant tower concept as a viable solution to addressing remote field development without conventional marine lifting and installation assets. Key steps and processes entailed overcoming challenges associated with an execution with first-of-a-kind elements under an aggressive schedule.
The buoyant tower design facilitated overcoming both the first-of-a-kind and the aggressive schedule challenges. The design concept of four large cylindrical tubes offered geometries conducive to construction identification of repetitive modular subassemblies. Strategies of prototyping-for-lessons-learned and subcontracting-for-schedule were recognized as means of overcoming challenges and are presented in the discussion.
The topside and support frame designs represent conventional construction by Gulf of Mexico benchmarks. However, both scopes posed first-of-a-kind and aggressive schedule challenges to a Chinese shipyard unfamiliar with offshore construction scopes under a fast-track execution. Strategies of contract provisions tailored for fast-track execution, schedule-friendly assembly methodologies, and high HSEQ standards were similarly recognized as means of overcoming challenges and are presented in the discussion.
Lessons learned and further opportunities for improvement are presented in the concluding discussion.

Introduction
The onshore construction of the CX-15 buoyant tower project entailed fabrication of three primary scopes: the buoyant tower hull, its topside, and the topside support frame. See Fig. 1. The onshore load-out of the CX-15 buoyant tower project entailed the movement of two primary scopes onto the transport vessel: the buoyant tower hull and its topside assembled upon the topside support frame.
Liuhua 11-1 FPS Dry-dock Upgrade and Life Extension - Project Scope and Execution
Authors: Zhong Wen Jun , Mao Jia You , Gao Qi , Yang Liang , Liu Yi Yong 
Published: May 2013

Abstract
Liuhua 11–1 FPS, which named ‘Nanhai TiaoZhan’, is a major component of LH 11–1 oil field development. It was a modified drilling semi-submersible converted from a Sedco 700 series semi-submersible mobile offshore drilling unit (MODU) before 1995. The LH 11–1 field has been in production since 1995. The FPS had been already exceeding its original design life with serious plate corrosions and aging equipment in 2011. At the same time, a new oil field Liuhua 4–1 (OTC-24042), about 11 km away northwest LH 11–1, was in development planning with the utilization of LH 11–1 FPS facilities through a subsea tieback. Therefore, additional topsides capacities and the life extension of this aged semi-submersible FPS became necessary.
The original design life of LH11–1 was 10 years from 1995. The main objectives of this dry-docking upgrading project included a 15-year continuous service life extension, the resolution of existing corrosion issues on the FPS and the field development supports for LH 4–1 field. Details cover:–Upgrade existing power system to meet the field development requirements.–Repair, replacement or reinforcement of some pipes and structures of the FPS in order to extent its service life.–Re-install and increase topsides equipment capabilities through repairs or the replacement of new ones.–Improve the conditions of living quarters and the capacities of existing anti-pollution equipment for environmental protection purposes.
A well-planned and effective design, a good construction site implementation approach and a well-controlled progress management were the most important factors to achieve this project schedule target. In this paper, a detailed discussion of the designs and the refurbishment work of this FPS upgrading project with emphasis on technical and execution challenges and the measures taken during the project execution. This project provides a good example, on a real project with a tight schedule, for the upgrading and the life-extension of an aged deepwater floating production system.
Exploration and Resource Definition of Offshore Titano-Magnetite Iron Sands, on the West Coast of New Zealand
Authors: Brown Matthew Earle Dunlop 
Published: May 2013

Abstract
Trans-Tasman Resources Limited (TTR) was established in September 2007 in New Zealand to explore, assess and develop the off shore titano-magnetite iron sand deposits, located off the west coast of the North Island of New Zealand.
TTR holds exploration permit(s) and a prospecting license granting exclusive mineral rights over 9633 km2 of seabed, within New Zealand's territorial and Exclusive Economic Zone (EEZ) waters. Subsequent to a large airborne magnetic survey, TTR has undertaken a series of shallow and deep drilling campaigns which have defined an initial JORC1 mineral resource. This JORC compliant mineral resource was defined by Golders Associates on the basis of drilling campaigns that were performed using in house designed and operated drilling units, the first of its kind in the world.
TTR is developing innovative solutions for all aspects of its exploration and feasibility studies. In relation to exploration, TTR are competing in an environment which has offshore contractors and equipment focused on the petroleum industry, therefore it has been essential that TTR remain innovative to ensure cost effectiveness, fit for purpose and industry standards (JORC) are paramount. Exploration to date has enabled TTR to estimate an offshore titano-magnetite iron sand resource, using low cost marine reverse circulatory drilling units developed specifically for this purpose (patent pending) in conjunction with other exploration techniques.
The purpose of this paper will be to discuss some of the main challenges in the exploration and the subsequent engineering studies used in the feasibility studies for the development one of the world's first large off shore mineral resource of iron ore. The key strategic advantage of the envisaged off shore wet mining operation would be its much lower capital cost compared to land based operations, as no deep sea port or heavy gauge rail is required.
Drill Cutting Remediation with ROV Technology
Authors: Kros Hans 
Published: May 2013

Abstract
Drill cuttings are produced by the volume displaced in the well. Wells consist of inter annular strings. As the strings are installed, the spoil it displaces are typically expelled on the seabed. Fill is expected to be carried away by current, or deposit on seabed but do not affect well accessibility. Voids inside casing are displaced cement.
Effect of Boundary Conditions, Flow Rate, Slug Length, and Slug Frequency on Slug Flow Induced Vibration in a Pipeline Span
Authors: Jia David 
Published: May 2013

Abstract
This paper expands on the work described in OTC 22935 (Slug Flow Induced Vibration in a Pipeline Span, a Jumper, and a Riser Section [1]). Different boundary conditions of the pipeline span, flow rates, slug lengths, and slug frequencies are investigated for slug flow induced vibration of the pipeline span using the methodology proposed in OTC 22935. Coupled three-dimensional CFD of multiphase flow and transient nonlinear Computational Structural Dynamics (CSD) are implemented in fluid domain and structural domain. Recommended guidelines for reducing slug flow induced vibration in pipeline spans are generated from this investigation. Recommended guidelines for slug flow analysis using CFD alone or using coupled CFD with CSD are also presented.
This paper has important and practical applications in designing pipeline spans and field operation of flow assurance to resist and reduce slug flow induced vibrations and fatigue damage due to slug flows in pipelines.
The results illustrate the process of slug formation and decay inside the pipe, and the dynamic response of the pipe, including dynamic stresses and frequencies for different boundary conditions of the pipeline span, flow rates, slug lengths, and slug frequencies. The effect of above variables on slug flow induced vibration of the pipeline span has been quantified in detail.
This paper quantifies slug formation and decay in a pipe while the pipe is also vibrating in response to this slug flow, accounting for the interaction between the two domains, for different boundary conditions of the pipeline span, flow rates, slug lengths, and slug frequencies. This paper provides a practical and very realistic tool for analyzing slug flow induced vibration and its induced fatigue damage and potential resonance response in pipeline spans. Important guidelines for better designs of pipeline spans and better management of flow assurance in field operation to resist and reduce slug flow induced vibration are proposed.

Introduction
Internal flow induced vibrations (FIV) have been observed in subsea jumpers during operation in subsea developments. Among the internal flows, slug flow is one of the most complicated phenomena in subsea pipelines, jumpers, and risers. A methodology for realistically modelling slug flow induced vibration in pipeline spans, jumpers, and risers was proposed in OTC 22935[1]. This methodology provides solutions to the slug flow induced vibration problems that DNV-OS-F201 (October 2010) [2] does not address. This paper expands on the work described in OTC 22935. The methodology proposed in OTC 22935 is used to investigate the effects of boundary conditions of a pipeline span, flow rates, slug lengths, and slug frequencies on slug flow induced vibration of the pipeline span. The numerical simulation examples are presented to illustrate the effects. A summary and conclusion is provided after the numerical examples.
Flow assurance modeling using an Electrical Trace Heated Pipe-In-Pipe: From Qualification to Offshore Testing
Authors: Nebell Frode , De Naurois Herve J , Parenteau Thomas , Decrin Marie-Kathleen 
Published: May 2013

Abstract
The use of subsea technologies and innovative field architectures as development solutions is fast becoming a reality. Thermal management is a key issue and using electrical heating such as the Electrical Trace Heated Pipe-in-Pipe (ETH-PIP) can be considered as an alternative to fluid circulation or chemical injection for preservation purposes.
The ETH-PIP is a standard Pipe-in-Pipe enhanced with 4 heat trace cables, and 2 DTS optical fibers spiralled against the inner pipe and covered by a high performance thermal insulation. As part of TOTAL qualification for the ISLAY project, the world first field development using subsea ETH-PIP technology, significant efforts have been put on the development and validation of flow assurance models able to predict the interaction of the active heating system with hydrocarbon mixtures during production, shut-down and restart.
This paper reviews and describes the development of the necessary models required to perform the thermal design and the flow assurance calculations all the way to the elaboration of a control system for monitoring the subsea operations. The focus has initially been put on the elaboration of a CFD model able to fully capture the local thermal behavior of every component. Finally, a simplified model describing the ETH-PIP thermal behavior is introduced into a multiphase flow simulator (Olga or Leda) to perform the necessary flow assurance calculations predicting the production fluid behavior during the transient active heating operations.
This paper also assesses the validation of the models. During the TOTAL qualification process, a 12m test rig has been set up for the validation of the the U value, cooldown and warm-up predictions coming from the CFD and Multiphase flow models. A larger scale validation has been performed comparing the fiber optics measurements to the model predictions during the commissioning test after installation. As an ultimate validation step, a complete offshore test has been realized during the Islay September 2012 shut-in period, where a series of warm-up, temperature maintainance and cooldown took place and successfuly compared to the models.
The elaboration and the validation of the ETH-PIP flow assurance model using CFD and Multiphase flow simulations enable the design and the prediction of the production fluid behavior during any operating scenarios. The developed models also open the door to the elaboration of a live monitoring system of the flowline thermal behavior which fully enables the ETH-PIP system operability for offshore operations.
CappingStack Demonstration in the US Gulf of Mexico
Authors: Massey Marty 
Published: May 2013

Abstract
350 words or less summarize the paper stating significant new information and conclusions.
In July 2010, following the Deepwater Horizon incident, ExxonMobil, Chevron, ConocoPhillips and Shell committed to providing an enhanced containment response capability. These founding companies recognized the need to be better prepared in the event an operator lost complete control and subsequent containment of a well in the deepwater U.S. Gulf of Mexico. This led to the formation of an independent, not-for-profit company, Marine Well Containment Company (MWCC), which would develop, maintain and advance well containment systems for operators in the deepwater U.S. Gulf of Mexico. Following formation, MWCC gained six additional members: Anadarko, Apache, BHP Billiton, BP, Hess and Statoil, for a total of ten member companies. This alliance signified unprecedented industry collaboration and is a key reason that drilling resumed in the U.S. Gulf of Mexico, enabling industry to get back to work.
Shortly thereafter, MWCC's interim containment system (ICS) became available in February 2011 for use in the deepwater U.S. Gulf of Mexico and in March 2011 the first MWCC-cited permit was granted. The development of the ICS was a significant milestone and direct result of a shared commitment by industry to improve previous response capabilities. The system exemplifies MWCC's founding purpose of being continuously ready to respond to a deepwater well control incident in the U.S. Gulf.
The company's mission was validated in summer 2012 when the Department of the Interior (DOI) and the Bureau of Safety and Environmental Enforcement (BSEE) requested that MWCC demonstrate the capabilities of its containment system, including a physical deployment of its capping stack - the centerpiece of the containment system - in the deepwater U.S. Gulf of Mexico. Through this exercise, and in partnership with Shell Oil Company, MWCC successfully initiated mobilization of its containment system and deployed the capping stack offshore to a simulated well where it was lowered approximately 6,900 ft. into the water. The capping stack landed and latched onto a simulated wellhead, where all necessary functions were completed and pressure testing confirmed the ability to control a well. Through this exercise, MWCC demonstrated an operator's ability to safely and effectively cap a well and showcased the team's ability to respond in an effective manner.
A Mature Southern North Sea Asset Considers Conversion to Wet Gas Operation Which Requires the Development of Compatible and Novel Chemistries for Flow-Assurance and Asset Integrity
Authors: Morales Noah L. , Anthony Jacob , Garming Johanna F.L. , Trompert Ruud A. , de Vries Gert J. , Webber Peter Andrew 
Published: May 2013

Abstract
As assets in the Southern North Sea continue to mature the tie in of new (high pressure) wells becomes more challenging. Additionally, the operators may consider centralizing their processing, increasing the complexity of the system. The wet gas then has to be transported over longer distances. Moreover, a greater emphasiss than before on the environment has created a drive to reduce production chemical usage. These factors combined have set new and challenging requirements for the chemicals that are to be applied to protect the existing facilities against hydrate formation and corrosion. Conventional off-the-shelf technologies were not able to meet the tough challenges, and required the development of a novel, and fit for purpose kinetic hydrate inhibitor (KHI) and corrosion inhibitor (CI).
The minimum performance requirements for the KHI included protection against hydrate formation at conditions of 8 degrees Celcius subcooling and 200 hours of hold time. Besides the high level of subcooling and extended hold time, several secondary chemical properties were essential for successful application of the developed product. These included: solubility of the KHI and CI at elevated temperature and high salt concentrations (independent of each other and together), the chemicals are to be formulation in methanol and functionally compatible, have a minimum impact on oil in water and water in condensate separation, have low reservoir impact with produced water reinjection (PWRI), be HSSE acceptable (CEFAS sub-warning free) and comply with certified chemical cleanliness standards (SAE Class 6) to enable trouble-free umbilical application. All of these requirements were able to be met for the developed product packages.
This paper describes the qualification process, lessons learned and the first successful field application of the newly developed chemistries into a recently developed reservoir block in the southern North Sea.
Thermoplastic Composite Riser Guidance Note
Authors: Echtermeyer Andreas , Steuten Bart 
Published: May 2013

Abstract
A new class of flexible risers is being developed: bonded fiber reinforced thermoplastic risers. These risers have some characteristics which are similar to unbonded flexible risers and some similar to bonded composite risers, giving them very interesting overall properties. In order to apply this promising technology its functionality and safety should be ensured. For this reason a new guidance note is being developed in a joint industry project, describing design requirements, material characterization and test methods.
The guidance note is performance based allowing a wide range of designs and optimization for the application. It addresses the design issues from the standards of related products, DNV-RP-F202 " Composite Risers" and API 17 J " Specification for Unbonded Flexible Pipe". Since bonded thermoplastic fiber reinforced pipes are not directly covered in the existing riser standards, any aspects related to this class of material are developed new.
An overview is given how the guidance note is organized and how the requirements are described. The guidance note addresses load cases and environments to consider. It lists the failure mechanisms that need to be controlled. It gives design criteria or test requirements for each failure mode to show that none of the critical failure mechanisms will happen during the design life. Full-scale test requirements are also addressed. Special emphasis is given to the end fittings. They will have to be qualified by a combination of analysis and testing.
Since long-term performance is the most critical question for ensuring performance during the lifetime, cyclic fatigue and stress rupture (static fatigue) will have to be considered for all failure mechanisms and all environments. Long-term performance is characterized using the pyramid system. Basic properties are established on the material level based on many tests. Special conditions and component performance are tested on a few samples for comparison.
Thermoplastic composite risers designed according to this guidance note should be fit for purpose during their design life.

Introduction
A new class of risers is being built: thermoplastic composite risers (TCR). These risers can have flexibility order of magnitude higher than steel risers but less than unbonded flexible risers while their construction and strength is similar to a bonded composite. The high flexibility of a bonded construction is achieved by making the risers of high strength continuous fibers (e.g. glass or carbon fibers) combined with a thermoplastic matrix with a high strain to failure. The concept of such a riser pipe is shown in Figure 1. Figure 2 shows an example pipe being tested under pressure and bending.
The New Risk Perspective in Corrosion Management
Authors: Ripley Graeme , Koch Gerhardus , McKay David 
Published: May 2013

Abstract
This paper describes a risk-based approach for corrosion management of offshore floating structures. The objective of this approach is to reduce the risk of corrosion related failures, reduce the associated downtime, while improving the cost-effectiveness of corrosion inspection and maintenance.
Corrosion is increasingly a significant challenge to the offshore industry and attributed to: an aging worldwide offshore fleet; assets being kept in operation for prolonged periods of time; units operating beyond their original " design basis"; and newer larger vessels in deeper, harsher environments with less opportunity for ship yard repair. Corrosion is particularly detrimental to the integrity of the unit, and if not managed properly will increase maintenance costs and downtime costs, possibly reducing the useful operational life of the unit. Although, there are several existing offshore corrosion design standards, experience still reveals a number of assets in poor and critical condition due to corrosion.
Clearly there is a need for a holistic approach on corrosion management during the full operational life of the asset. The presented methodology is based on the principles of ISO 31000 (Risk Management - Principles and Guidelines) to provide a solid consistent framework for corrosion management. The risk-based corrosion management process for offshore structures described in this paper consists of five (5) basic steps: Pre Assessment; Screening and Risk Ranking; Detailed Examination; Remediation and Repair; and Life Cycle Management.
Adopting the described risk based corrosion methodology will provide confidence to the operators and demonstrable evidence to key stakeholders that corrosion is being managed on their assets. It will account for life extension, reduce the risk of corrosion failure, and lower the cost of inspection and maintenance.