bluuebunny/crossref_metadata_2025_split huggingface dataset:
Project Management, Local Content and Value Delivery
Authors: Idachaba Francis E. , Wokoma Esther 
Published: June 2014

AbstractThe local content policy is enforced by Governments to get local contractors more involved in the supply of services to the Oil industries in their countries so that funds spent on foreign companies for the provision of these services can be retained in the country. This increases the capacities of these companies at providing jobs and reducing unemployment in their countries. The Oil industry in Nigeria spends over $15Billion annually for services such as fabrication, procurement and engineering. These services can be provided by local companies. The main issue with the implementation of the local content policy is in the quality of services rendered by local companies which raises the question as to whether the value delivered is commensurate with the funds spent. Other issues include: Do these companies possess the required expertise to enable them deliver to the required standards? Are these companies being run in such a manner as to grow them into multinational companies capable of providing service to the global oil and gas companies? With the discovery of oil in other African countries, Nigeria should be a source of high quality and low cost alternative for the supply of the required technical expertise in these countries. The local content bill can only be successful if the benefitting local companies grow in terms of technical, financial and managerial capacities to be able to compete globally. For this to happen, the companies must be made to conform to international best practices, the scope of projects to be delivered must be thoroughly understood and the contract terms should include incentives for timely delivery of projects and services within the cost, schedule and quality. The contract terms should also include penalties for slippages by either party and these terms should be adhered to very strictly.
SCORCH JIP - Feedback on MIC and Pitting Corrosion from Field Recovered Mooring Chain Links
Authors: Fontaine Emmanuel , Rosen Jeremy , Potts Andrew , Ma Kai-Tung , Melchers Robert 
Published: June 2014

Abstract
Forensic investigations on severely corroded (pitted) chains recovered from the mooring systems of two FPUs in West Africa and Indonesia are described. During the course of the SCORCH JIP, it became apparent that a similar phenomenon had been experienced by other JIP participants indicating that it may be a common problem deserving attention. The conclusion of the present investigation is that the large pits most likely can be attributed to Microbiologically Influenced Corrosion (MIC). Where pitting occurred, the pit depth growth rate was found in instances to be up to 10 times the uniform corrosion rate, with pits distributed approximately uniformly but randomly around the link and the bar circumference. Destructive tensile tests of the samples indicated residual strength that was at worst 25% below as-manufactured estimated As-new Breaking Load (ABL). The correlation of loss of strength with loss of metallic area due to uniform and pitting corrosion indicated that breaking load cannot be treated simplistically, and requires more sophisticated consideration of the pit geometry and its location with respect to areas of high stress within the link.
New Design Of Lightweight Flexible Pipe For Offshore Oil Offloading Transfer
Authors: Do Anh Tuan , Legeay Sebastien , Pere Jean Marie , Charliac David , Roques Jean Philippe , Karnikian Alexandre 
Published: June 2014

Abstract
Spread moored FPSO (Floating Production and Storage Off-loading) vessels are typically used in the large West African oil fields. The oil from these vessels is transferred to shuttle tankers via an Oil Loading Terminal(OLT). This usually consists of 2 to 3 flexible offloading lines installed between the FPSO and a Single Point Mooring (SPM) with large internal diameter for 24 hour offloading. The final connection between the SPM and the shuttle tanker is made by floating hoses.
Currently the flexible off-loading lines (OOL) are designed with steel wire armor, as typically used in the Offshore West Africa Fields. With pipes reaching 23? internal diameter and up to 2300m in length, the steel wires give the pipes a substantial weight generating the need for a large number of buoyancy modules to minimize the tension at the FPSO and OLT. These modules significantly add to both the cost and the installation time.
Carbon Fiber Composite (CFC) is characterized by its light weight and exceptional fatigue performance, with the ability to be manufactured as an armor wire in a long continuous single length (more than 4000 meters). It can be used as an alternative to steel wire armors to design an optimized flexible pipe structure with significant advantages:45% decrease in submerged weightPotential to install in double catenary configuration, without leading to excessive top tensionBuoyancy Modules are no longer required - installation is safer and quickerRiser configuration is no longer impacted by fluid density
These advantages allow greater flexibility in the position of the FPSO relative to the SPM with a fixed length of riser. Because CFC Armor is not susceptible to corrosion, service life of the flexible pipe is unaffected by breaching of the outer sheath and subsequent flooding of the annulus.
This new design of flexible pipe, together with the installation and operational configurations, will be presented in this paper. In order to demonstrate the suitability of CFC, the material performance testing in severe fatigue and ageing conditions will be disclosed. The economic viability will be demonstrated by showing how the material cost is offset by the elimination of buoyancy modules and faster installation. Additionally this technology enables flexible OOL risers to be produced in a long single length.
Operational overview of the first offshore production test of methane hydrates in the Eastern Nankai Trough
Authors: Yamamoto Koji , Terao Yoshihiro , Fujii Tesuya , Ikawa Terumichi , Seki Makoto , Matsuzawa Maki , Kanno Takayuki 
Published: June 2014

Abstract
In March 2013, the world's first field trial of gas production from marine methane hydrate deposits was conducted in the Daini Atsumi Knoll area of the Eastern Nankai Trough off the Pacific coast of Japan as a process to bring gas hydrates under seafloor to valuable energy resource. The technique used to dissociate the ice-like material was "depressurization method" that had been applied in the previous production test in Mallik site, the Northwest Territories, Canada in 2007-2008. Japan Oil, Gas and Metals National Corporation (JOGMEC) as a part of MH21, the Research Consortium for Methane Hydrate Resources in Japan planed and supervised the project with the funding of the Ministry of Economy, Trade and Industry (METI), and scientific supports from the National Institute of Advance Industrial Science and Technology (AIST). One production well with two monitoring boreholes were drilled in the test site for the test. Along with the flow test operation, intensive data acquisition program was planned and implemented to understand behavior of methane hydrate dissociation- bearing sediments against depressurization. To realize high degree of drawdown in relatively shallow formation below deepwater, several downhole devices were designed and installed.
The flow test started in the morning of March 12 and lasted until severe sand production forced to terminate the operation six days later. During the stable production term, gas flow rate was approximately 20,000m3 under atmospheric condition, and gas liquid ratio was larger than 100. A lot of data including formation temperatures, fluid pressure and temperature, and physical property changes in the formation were obtained. The data taken are under studies to verify applicability of the depressurization technique as a methane hydrate production technologies.
Decommissioning Costs Can Be Reduced
Authors: Stokes Alan William 
Published: June 2014

Abstract
Decommissioning Costs can be reduced. Many costs are higher than needed due to decisions made during the initial engineering and construction of an offshore oil or gas field. Five years of decommissioning data, throughout the world have been studied. Key areas have been identified where decisions made during design have affected the eventual decommissioning costs. Examples of possible decommissioning cost savings are listed.
Economics for 60, 000 barrels of oil per day oil field show that a reduction in decommissioning costs of 50% can increase the Project Net Present Value by 13%. The five stages of decommissioning an offshore development are described with the cost percentage split for each stage using North Sea data. The major cost drivers of a decommissioning project are stated. For each of the major cost drivers practical examples are given as how the costs could be reduced during design by changing the design. These changes will increase the choices for removal. The scope of the decommissioning studies during conceptual and detailed design are listed. Finally the missing technologies will be listed as experience has shown that cost reduction and safety can be enhanced if new technology could be developed.
The guidance for project design reviews is provided to direct designers and engineers so they can consider decommissioning as part of their work.
Challenges and Solutions of an Ultra-deepwater Dry Tree System for Drilling and Production in the Gulf of Mexico
Authors: Zeng J. , Smith D. , Wu W 
Published: June 2014

Abstract
This paper discusses the key challenges associated with the design of a Dry Tree Semi (DTS) global configuration with robust performance and easy execution, as well as the integration of the topside facilities with hull at quayside. The authors will address the issues associated with a safe wellbay design in order to satisfy all functional requirements of simultaneous drilling and production operations, and compensation of riser stroke. More importantly, the authors will present technically robust and cost-effective solutions to overcome these challenges through extensive engineering assessment, computer simulation, and model test verification.
The authors focus on improving functional and operational safety of the DTS system while minimizing project execution risks. Through innovative design, engineering analysis, and model test verification of the DTS system, important and valuable results will be presented in this paper, which include overcoming various conflicting issues associated with wellbay arrangement and functional performance under simultaneous drilling and production operations; compensating for the most challenging issue of riser performance on a DTS utilizing long stroke riser tensioner technology; and deriving a hull-mooring-riser global configuration that not only carries robust performance during operation, but also offers the benefits during project execution.
MWCC's Expanded System: Enhancing Well Containment in the U.S. Gulf of Mexico
Authors: Massey Marty 
Published: June 2014

Abstract
This paper will include a technical overview and progress update on Marine Well Containment Company's (MWCC) expanded containment system (ECS), which is being constructed to further enhance industry's containment capabilities in the deepwater U.S. Gulf of Mexico. In support of that mission, MWCC established two shore base locations in strategic Gulf Coast communities that will house, test and maintain the ECS equipment. The shore bases – located in Ingleside, Texas and Theodore, Ala. – provide MWCC with the ability to respond to a well control incident safely and effectively.
Together, the ECS and shore base locations enhance MWCC's deployment capabilities and allow the company to keep pace with its members' needs. The ECS will provide greater containment capacity in deeper water depths and enhance SIMOPS and controls capabilities. The expanded system will be able to cap and flow a well in depths up to 10, 000 feet and has capacity up to 100, 000 barrels of liquid per day (and up to 200 million standard cubic feet per day of gas).
The shore base locations will house topsides processing equipment for modular capture vessels (MCVs) and subsea equipment. The providers were selected because of their ability to meet MWCC's operational and technical requirements, thus creating a unique infrastructure for comprehensive and integrated support that allows MWCC to carry out its mission to be continuously ready to respond.
Construction is underway on the ECS, under the direction of the Marine Well Containment System project team, and delivery of key components to the shore base locations has already begun. The established shore bases signify an important milestone in the delivery of the ECS, which is scheduled for completion in 2014.
The availability of the ECS – which represents an investment of more than $1 billion by MWCC's ten members – demonstrates unprecedented industry collaboration and allows MWCC to keep pace with its members' needs. The ECS, together with the established shore base locations that will house this equipment, will enhance MWCC's ability to respond to a deepwater well control incident in the U.S. Gulf of Mexico.
Enhancing Well Control Through Managed Pressure Drilling
Authors: Gabaldon Oscar , Culen Martin , Brand Pat 
Published: June 2014

Abstract
In addition to enhancing drilling safety and performance, MPD offers new options for well control. Because MPD allows rapid changes in bottom hole pressure, the response to an unwanted influx during MPD operations is not necessarily to shut-in and weight-up. Instead, the required overbalance can be regained dynamically to stop an influx, as well as circulate it from the wellbore. This fundamental difference from conventional drilling allows components of the primary barrier envelope to be used without having to activate secondary well control equipment, as the MPD system is designed to handle influxes to a maximum size. Most commonly in MPD operations, this can be achieved by closing an MPD choke, while circulation is maintained. The advent of dual gradient drilling offers further variation in dynamic well control practices.
MPD is a deviation from traditional drilling practices and the technique is relatively new to industry. MPD systems are designed to detect and control influxes of a certain size, however, many MPD operations revert quickly to conventional shut in procedures when confronted with an influx regardless of the size. Effectively, all influxes are treated as kicks.
Inconsistent definitions and misunderstandings of MPD systems' equipment and capabilities amplify the problem of determining when dynamic operations are appropriate. The switch from influx management with the MPD system to conventional well control is governed procedurally through the definition of operational decision points based on influx indicators and surface backpressure during drilling. Quantification of manageable influx size is not standard. The onus is on the operator to define these decision points such that influxes are safely managed by the MPD system, while the rig handles kicks. Further, the use of MPD equipment can also be used to limit the resultant size of an influx that has become a kick, demonstrating that MPD equipment can ultimately enhance drilling safety, in most cases.
In this paper, differentiation between appropriate MPD operations using the primary and secondary barrier envelopes is proposed. The work explores the key factors that must be considered in determining when the appropriate initial response to any influx is dynamic or conventional. A common understanding throughout industry of the safety related aspects of MPD may lead to the use of such systems on every rig, defining the new normal.
A Gyroscope Guidance Sensor for Ultra-Deepwater Applications
Authors: Richardson D. A. 
Published: June 2014

Abstract
The Laserlith team designed an inertial guidance system for ultra-deepwater drilling. The system was based on micro-electro-mechanical systems (MEMS) gyroscope technology; with a demonstrated gyroscope mechanical sensor design integrated with robust readout circuits that can operate in the down-hole environment, i.e., high temperature and high vibration/shock. MEMS gyroscopes enable this inertial guidance system to be positioned next to the drill bit, which is a significant improvement over existing magnetometer guidance systems that must be installed 50 to 80 feet behind the drill bit. The shortened reaction reduces drilling time and drilling cost. The system could potentially enable a greater volume of the reservoir to be accessed from a single surface location, decreasing costs and environmental impact.
The three main components to the work included high temperature circuit design, optimization of the MEMS sensing element, assembly and test.
The successful development of this technology can substantially reduce response time of drilling measurements by providing the ability to install the inertial sensor next to the drill bit. Improved accuracy and reduced drilling time accelerates the rate of commercial production, as well as exploration in emerging plays. A MEMS gyro can significantly reduce drilling time for casing window cutting applications, intermediate radius re-entry applications and steering applications.
Subsea Well Response Project enhances international well incident intervention capabilities
Authors: Lewis Keith , Kaczmarski Andrzej , Lowery Rock , Stanga Heather , Kallaway Kris 
Published: June 2014

Abstract
The Subsea Well Response Project (SWRP) was established in 2011 on the recommendation of the International Association of Oil and Gas Producers as part of its efforts to further improve subsea well capping response readiness and to further study the need for, and feasibility of, global containment solutions. Through SWRP, international oil and gas companies have worked together on an unprecedented scale to share knowledge, expertise and best practices to enhance international subsea well incident intervention capabilities and to minimise the environmental impact in the event of a subsea well control incident.
This paper will present a summary of the key results from the Project, including the research and technological advancements that will benefit the whole industry.
SWRP has undertaken extensive studies into existing technologies and capabilities and the availability of components already stored around the world, in order to design a well intervention toolbox, including capping and dispersant injection capabilities that can be used in different offshore regions around the world. The first elements of this integrated intervention system are now available to the industry, including four subsea capping stack systems and two subsea incident response toolkits for debris clearing and the subsea application of dispersant.
Furthermore, SWRP developed a concept for a subsea well containment solution which relies extensively on existing drilling rigs and commercially-available well-testing equipment to capture fluids from an incident well and flow them to the surface for processing and disposal (in the unlikely event of a well capping operation being unable to completely stop uncontrolled flow of hydrocarbons to the sea).
Based on this concept, SWRP carried out further engineering and modelling studies to develop a technically feasible subsea well containment template system. This template system consists of a combination of (i) items of long-lead equipment referred to as the containment toolkit, and (ii) existing capture vessels and various items of industry standard well testing equipment.
SWRP is collaborating with Oil Spill Response Limited to make this advanced capping, dispersant and containment equipment available to the wider industry, on a commercial basis.
The subsea well owners/operators will benefit from planning in advance in order to prepare appropriate contingency response plans for a well control incident and potential emergency deployment of the integrated subsea well intervention system.
Ultra Deepwater Reel and Flexible Pipelay Vessel for Pre-Salt Field Developments
Authors: Christiani Erik 
Published: June 2014

Abstract
Reeled & flexible pipelay has normally been utilized in fully developed and matured offshore oil and gas field areas with close proximity to onshore support, onshore logistics and short offshore transit distances to onshore spoolbases for loading the pipeline stalks or flexibles onto the reels. This is normally an activity that requires comprehensive planning both onshore and offshore and is often on the critical path of the overall pipelay campaign.
New discoveries in remote locations such as the Gulf of Mexico deep water field developments often have long transit times from established spoolbases and port facilities, hence rendering certain reeled-lay scenarios uneconomical. This paper will discuss the advantage of the next generation of pipelay vessel suitable for remote offshore locations in hostile environment. This new generation of multi-lay vessels utilizes portable reels to eliminate critical path activities at the spool-base, which often causes delays and other problems. In addition to this, these vessels, when configured correctly, allow installation of in-line structures conveniently and safely together with integrated touch down monitoring. As a bi-product or complement to the portable reels, these vessels also feature significant offshore lifting capabilities, which further enhance their flexibility as a full field development vessel. In addition flexible and umbilical products can be combined with-in the pipelay vessel on the vertical reels or the carousels with-in the pipelay vessel hull, i.e. avoiding multiple vessel mobilizations for a reeled and flexible pipelay campaign.
Traditional deepwater pipelay vessel types will be compared to the multipurpose reeled and flexible lay vessel with and without onshore facilities and logistical infrastructure support close by. This will validate the robustness of installing deepwater pipelines and flexibles in remote locations using this new type of reeled pipelay vessel.