bluuebunny/crossref_metadata_2025_split huggingface dataset:
Gas-2-Pipe™, A Concept for Treating Gas to Rich Gas Quality in a Subsea or Unmanned Facility
Authors: Fredheim Arne Olav , Johnsen Cecilie Gotaas , Johannessen Eivind , Kojen Gry Pedersen 
Published: April 2016

Abstract
Field developments on the Norwegian Continental Shelf (NCS) have become cost intensive both for greenfield and for tieback / brownfield developments. A large existing infrastructure with future free capacity is available consisting of processing platforms and transport systems. The objective for the Gas-2-Pipe™ concept is to reduce capex/opex intensive topside modifications and topside weight and space constraints by utilizing the established infrastructure and host facilities in a flexible way.
The process concept treats a gas dominated well stream in order to meet the so called rich gas transport specifications. Rich gas specifications in the Norwegian transport system are mainly related to a cricondenbar specification in the range of 105 to 110 bar and to a water dew point specification of typically -18 °C at 70 bar. Gas is treated in two steps where hydrocarbon dew point is obtained by sea water cooling and pressure reduction to form a gas and a liquid phase. Water content in the separated gas is reduced by injecting lean glycol through a compact mixer unit and separating out the rich glycol from the gas in a separation unit. Gas is also cooled by sea water in the dehydration process. A single- or two-stage dehydration process may be used. Considerations regarding process design, process parameter selection and glycol distribution rate are given.
After treatment, the gas is compressed to the necessary export pressure and injected directly into the pipeline. Processing takes place in a subsea or topside unmanned environment where necessary utilities are imported from one or several hosts. Required utilities are typically power- and control system and glycol for gas dehydration. Produced liquid hydrocarbons and water is routed to a host for further stabilization and treating. The concept may become an enabler when nearby host capacity is gas constrained and traditional tie-back is too cost intensive.
The concept is seen as an enabler for field development of gas dominated fields with a potential for cost reduction compared to conventional concepts. The main gaps are identified and a qualification strategy for the key technology elements is given, ranging from small scale and pilot scale testing to implementation of new technology elements in traditional field developments.
A Custom Made Organization to Manage Deep Offshore Brown Field Projects of TOTAL E&P Angola Block 17
Authors: Morard Jean-Hervé 
Published: April 2016

TOTAL E&P Angola celebrated mid 2015 its 2 Gbbl produced on its deep offshore Block 17 with its 4 FPSO’s (Girassol, Dalia, Pazflor and CLOV).
From 2008, numerous brownfield projects opportunities have been identified and developed in order to limit the natural decline of the producing fields and to maximize the production of the existing FPSOs: infills wells, enhanced activation by seabed multiphase pumping, process topsides debottlenecking, tie-back of satellite and marginal fields…
In 2012 a dedicated structure has been created in TOTAL E&P Angola to manage the execution of all Brownfield Projects on Block 17.
This paper presents the objectives, strategic axes, organization, challenges and achievements of the Block 17 ‘Project Brown Field’ Direction.
Integrated Decommissioning – Increasing Efficiency
Authors: Price William R. , Ross Benjamin , Vicknair Benton 
Published: April 2016

Abstract
As offshore fields reach the end of their economic lives, there is an increasing need to decommission platforms and other structures to promote safety, protect the environment, and comply with governmental regulations. Decommissioning is a complex undertaking, requiring a range of equipment and expertise. Especially in the current economic environment, oil and gas operators are seeking ways to decommission their older facilities while controlling costs. This paper describes a more efficient method of platform decommissioning that integrates multiple services and manages them as a single project, with the objective of completing the decommissioning job safely and efficiently at a fixed cost to the operator.
This approach was implemented for an operator in 2015 to decommission an eight-pile platform in the South Timbalier area of the Gulf of Mexico. Project implementation involved extensive planning, the integration of four services that are typically provided separately, project management and site coordination, as well as lump sum contract terms to facilitate cost control by the operator.
Rov Based Survey: A New, More Effective Approach
Authors: Oskarsson Ola 
Published: April 2016

Abstract
Objectives/Scope: The paper presents results from developing a specialized Survey-ROV (Remotely Operated Vehicle) aimed at higher speed and unsurpassed resolution. Multi beam, laser and photogrammetry data will be presented.
Methods, Procedures, Process: The Surveyor Interceptor is a newly developed specialized Survey ROV. It has a hydro dynamically favorable hull, thin tether, and powerful propulsion to allow high resolution surveys, close to the seafloor, at speeds up to 10 knots.
The ROV was built during 2014 and has been tested during Quarter 1 2015. This paper presents results from tests and the first commercial tasks for the new SROV. The ROV has been used for pipelines, route surveys and environmental surveys in the North Atlantic at water depths between 50 -1200m. Acquired data will be presented. Performance as well as resolution and accuracies obtained are above the initial specifications and new technologies are developed.
The combination of high resolution equipment in a stable hull, renders accurate data for enhanced risk mitigation of offshore installations
Results, Observations, Conclusions: The SROV has surveyed with average speed of above 4 knots at several hundred meters water depth while collecting data from Multibeam echo sunders, laser bathymetry, still photos, photogrammetry, Side Scan Sonar’s and Sub Bottom Profilers. The Underwater Navigation results are greatly improved by the use of inverted USBL, DVLs and INS systems. The vehicle is very stable at speed, thus rendering clean data with very little outliers. All in all the total concept can reduce the cost of pipeline and route surveys with improved data quality.
Integrity Management decisions based on data from the SROV will greatly reduce risk of offshore pipelines and installations.
Novel/Additive Information: Specialized Survey ROV’s will lower the cost for Pipeline Inspection and Environmental Impact Surveys while rendering 3D models and resolution of hitherto unseen density and accuracy.
Gullfaks Subsea Compression - Subsea Commissioning, Start-Up and Operational Experiences
Authors: Birkeland Bjørn , Bøe Caroline , Jensen Roger Oen 
Published: April 2016

The Gullfaks subsea compression project is a brownfield development which aims to extend the plateau production and increase total recovery from the Gullfaks Sat. Phase II (L and M templates) with multiphase compression technology from OneSubsea. This is the world's first subsea wet gas compressor project, and the compressors are installed at approximately 135 m water depth. The subsea compressors will boost the unprocessed gas well stream containing liquids to Gullfaks C from year 2015 to 2030. The compressor station will be located at the M and L templates and the tie-back distance to Gullfaks C is approximately 16 kilometer. The compressor station is equipped with 3 future hubs for tie-in of additional fields in the area, which enables flexibility to the system.
The Gullfaks Compression System (GSC) main components consists of 2 multiphase compressors (WGC4000) with individual recirculation systems, 2 subsea process coolers, 1 flow mixer and 3 bypass headers. The flow mixer is located at the inlet of the station and the main purpose of this device is to dampen out liquid slugs and provide an equal homogenous split of multiphase flow to the two compressors when operating in parallel. The subsea cooler main purpose is to cool the well stream before compression in order to limit the compressor discharge temperature below the flow line design temperature in addition to increase compression efficiency.
The wet gas compression technology is applicable for most gas fields which will have use for pressure support at one stage. The system is quite simple i.e. there is no need for conditioning of the well stream.
The Gullfaks Subsea Compression station was started up October 7th 2015. This paper will describe the subsea commissioning phase, including lessons learnt from the subsea commissioning phase. In addition this paper will give an outline of the experiences gained during start-up and operational phase.
The wet gas compression technology could have an impact on brown field developments where topside weight capacity may be constrain. Such project could also have a positive impact wrt HSE as no tap in to existing topside process will be required. Last but not least, this is a cost efficient solution where the recoveries from the wells are improved in addition to accelerated production.
Floater and SURF Combined and Optimized Solutions
Authors: Seguin Blaise , de Roux Grégoire , Germanetto Florian , Beltrami Francesco , Shah Vinanti , Linder Samuel 
Published: April 2016

Abstract
It has long been recognized that value creation for deepwater projects is predicated based on robust front end engineering and field development planning. Realizing this value requires a multidisciplinary approach that considers early engagement with the SURF execution team and the field development planning specialists, engineering specialists and project execution expertise. This paper presents an overview of recent experience and an illustration of the benefits of this approach. The general principles of field development optimization are presented, with an emphasis on Floater and SURF packages as well as the cost drivers to optimize the interfaces between these packages.
This paper plans to explore the benefits of front end engineering design as it relates to early engagement of the SURF and Floater disciplines. The paper will examine through case studies topics such as: subsea production network alternatives, floater and riser conceptual and early phase design, and interfaces between the floater, riser and production system.
High-resolution Velocity Update Using Full Waveform Inversion: A Case Study in East Breaks, Gulf of Mexico
Authors: Bai Bing , Yu Guo , Wang Sunxi 
Published: April 2016

Abstract
In this case study located in East Breaks, Gulf of Mexico, we faced seismic imaging challenges caused by a mass-transport complex (MTC) below the seabed. The MTC is characterized by moderate-to-strong seismic velocity and amplitude variations due to both structural and stratigraphic inhomogeneities. Traditional tomographic velocity inversion methods could not provide sufficient resolution of the small-scale velocity anomalies within the MTC. As a result, seismic events below the MTC appeared distorted and out of focus. Multiple iterations of high-frequency full waveform inversion (FWI), up to 18 Hz, enabled us to derive a detailed velocity model of the MTC, thereby improving the seismic image beneath it. Detailed analysis at a deeper reservoir level showed that event continuity, gather flatness, AVO response and pre-stack P-impedance inversion were all improved after migration using the FWI-derived velocity.
LNG Tandem Offloading Solution: Ready for Deployment!
Authors: Duhamel Nicolas 
Published: April 2016

Abstract
The first worldwide offshore FLNG projects are moving up to construction and commissioning phases, with first gases most likely planned for the next two years. These floating facilities will operate in exposed environmental conditions (typically Hs up to 2.5m), under which it has been demonstrated that side-by-side offloading remains a safe and viable operation. The excellent track records of marine loading arms in the LNG industry; as well as the great economical advantage to distribute LNG to conventional LNG carriers, naturally led to the development of offshore loading arms, being the references on the FLNG market today.
Nevertheless, the higher performances, enhanced availability and the ability to relocate the FLNG in any location of the world naturally forced the FLNG projects owners to look carefully at LNG tandem offloading, as a natural way to offload as per FPSO culture. Whereas the main showstopper was the lack of maturity of LNG tandem offloading technologies a few years ago, latest developments made on the FMC ATOL (Articulated Tandem Offshore Loader) in partnership with oil & gas majors, DP suppliers and LNGC operators change the stakeholders dreams into reality.
The FMC ATOL has not only been validated through comprehensive kinematic, stress and fatigue analysis to confirm a 99+% operability in the harshest Australian type conditions, it has also been fully validated thanks to an 1/5 scale model tested under the harshest environmental conditions with third parties involvement.
Field proven components designs and technologies resulting of 50 years of conventional LNG transfer records and today of offshore side-by-side LNG transfer with loading arms are transposed to the ATOL LNG tandem transfer solution and prototype-tested to real project conditions, like the FMC ATOL swivel joint which successfully passed a long life test equivalent to a 10-year maintenance-free period (considering 1 offloading a week). These are 7 years of development and 30 000+ hours of engineering which rose up the technology readiness level high enough for the deployment of the FMC ATOL on field.
On top of that, a consolidated execution plan has been developed detailing a 30 months delivery time, including project specific engineering, purchasing, construction and tests. As part of this execution plan, the FMC ATOL has been developed emphasizing the turnkey approach, to minimize the integration works duration on the FLNG to a strictly limited number of mechanical and electrical interfaces. Such all-in-one design allows performing an extensive tests campaign on the ATOL before its delivery, inclusive of functional tests, static and dynamic tests and simulations of emergency disconnections.
This is how FMC Technologies provides performance, safety and reliability guarantees before the integration of the FMC ATOL on the FLNG, in mirror of how the success story of the FMC OLAF on Prelude FLNG project has been built.
An Improved Methodology on Design and Analysis of Offshore Wind Turbines Supported by Monopiles
Authors: Sahasakkul Watsamon , Nguyen Hieu , Sari Ali 
Published: April 2016

Abstract
A wind turbine shall be considered as an offshore wind turbine if the support structure is subject to hydrodynamic loading. Foundation design or soil-structure interaction is not clearly outlined in detail in the design standards for wind turbines, IEC 61400-1 (Design Requirements) and IEC 61400-3 (Design Requirements for Offshore Wind Turbines). The general approach in the IEC standards is to follow the API (American Petroleum Institute) design approach for offshore platform foundations.
In an API approach, the soil p — y curves are developed for the slender piles which are widely used for offshore oil and gas platforms. The failure mode of these slender piles is the formation of flexural plastic hinges. In contrast, the monopiles supporting offshore wind turbines are typically rigid with 3.5 – 6 m diameter and 30 – 40 m length. The failure mode of these monopiles likely involves rigid motion. Under extreme loading conditions, soil surrounding the monopile may fail because of large deformation due to such motion. Therefore, the API approach developed for slender piles may not be applicable for the monopiles.
An improved methodology for analysis and design of a 5-MW offshore wind turbine (OWT) supported by a monopile is presented in this study. The soil-monopile interaction under wind and wave cyclic loads is first studied using advanced finite element analysis (FEA) in ABAQUS. The results of the analyses are utilized to develop a set of p — y curves for the monopile. The FEA-based nonlinear p — y curves are input to SACS through user-defined subroutines. The coupled analysis includes soil-structure interaction and dynamic response of the tower and blades to wind and wave loadings. The fully coupled analysis is carried out using SACS-FAST integrated computational interface. Response of the wind turbine on the monopile is studied in a time domain using frequency domain inputs such as Kaimal spectrum for wind loading (TurbSim, NREL) and JONSWAP spectrum for wave loading in SACS. In a case study, the dynamic response of the 5-MW wind turbine and its monopile foundation obtained using the nonlinear p — y soil curves in the coupled analysis will be compared to the one obtained using an API approach.
Current State of the One-Trip Multizone Sand Control Completion System and the Conundrum Faced in the Gulf of Mexico Lower Tertiary
Authors: Techentien Bruce , Grigsby Tommy , Frosell Thomas 
Published: April 2016

This paper provides perspective on the current state of multizone completion technology and issues encountered in the industry with developing a system that offers increased capabilities to meet the ever-increasing challenges presented by the Lower Tertiary formation in the Gulf of Mexico (GOM).
Since the introduction of the first-generation multizone system approximately 35 years ago, the technology has continued to evolve to meet new well and reservoir challenges. The Lower Tertiary formation in the GOM is currently driving the need for further evolution of the current-generation multizone system. The Lower Tertiary reservoir requires deeper well depths, higher zone pressures, higher bottomhole temperatures (BHTs), and higher production rates as well as reservoir monitoring and reservoir control for improved reservoir management. These are just a few of the technical challenges for developing the next-generation multizone completion system.
In the intervening 7+ years after its introduction, the fourth-generation multizone system was successfully deployed in multiple ultra-deepwater wells in the GOM, along with dry and wet tree completions in the Asia Pacific area. This paper presents information on the associated demands for improved technologies, which will assist the industry understanding of the technical challenges related to drilling, completing, and producing in the Lower Tertiary formation. The paper discusses which requirements are optional and mandatory for future development and evaluation and how this will affect well architecture in the future. The multizone technology has proven to be an enabler for cost-efficient completions in the shallow well environment and a true enabler in the high-cost ultra-deepwater environment requiring high-rate fracture stimulation treatments.
Similar to previous systems, this fifth-generation multizone system is expected to have a significant impact on production and reservoir management. The proven technology will help operators overcome the completion challenges presented by the Lower Tertiary formation.
Degradable Metal for Use in a Fully Dissolvable Frac Plug
Authors: Fripp Michael , Walton Zachary 
Published: April 2016

Abstract
A new dissolvable frac plug has been developed for "plug-and-perf" style hydraulic fracturing applications. The dissolvable frac plug operates like a traditional frac plug and can be set anywhere in the wellbore to isolate individual zones. The new dissolvable frac plug is composed of a high-strength metal that degrades completely in wellbore fluids.
Traditional frac plugs are constructed from a composite material. After a hydraulic fracturing treatment is complete, traditional frac plugs create a restriction to production flow and must be removed. Thus, a separate intervention is required to mill out traditional plugs after fracturing. A novel dissolvable frac plug has been developed that eliminates the need for a separate mill run intervention into the wellbore. The new frac plug will degrade completely to leave an unrestricted wellbore for production. The high-strength dissolvable metal allows dissolution in water-based wellbore fluid, formation fluid, or production fluid.
Comprehensive laboratory testing was conducted on the dissolvable metal alloy for the new dissolvable frac plug. The dissolvable metal alloy is a metallic alloy that is combined with a dopant. The dissolution behavior is controlled by the interaction between the dopant and the rest of the metal alloy. Metallographic analysis illustrated the effect of the dopant on the dissolution of the metallic alloy. Dissolution is further influenced by the wellbore temperature. The high-strength alloy allows for the creation and use of dissolvable slips, which enables the complete dissolution of a frac plug that can be set anywhere within the wellbore.
The novel frac plug is designed for plug-and-perf applications and is composed of a new high-strength engineered metal that dissolves in water-based wellbore fluid, formation fluid, or production fluid. Complete dissolution of the frac plug eliminates the need for a separate mill run intervention into the wellbore, which helps reduce costs, operation time, and risks to personnel. This paper discusses the development of the dissolvable metal and the dissolution behavior of the metal upon exposure to wellbore fluids.
Improving Safety of Deepwater Drilling Through Advanced Instrumentation, Diagnostics, and Automation for BOP Control Systems
Authors: Nelson William R. 
Published: April 2016

Abstract
Among the contributors to excessive downtime for deepwater drilling are undetected failures in blowout preventer (BOP) control systems. These undetected failures result from the limited instrumentation of current systems, and require use of conservative criteria to decide if the BOP should be pulled to the surface for maintenance. The safety and risk effects of undetected failures are currently measurable only indirectly by the consequence of excessive non-productive time.
A reliability- and human-centered design approach has been developed for next-generation BOP control systems to improve the safety of deepwater drilling by providing additional redundancy and fault tolerance, more accurate information regarding control system health, and clear guidance for determining whether the control system should be reconfigured to compensate for failures or pulled to the surface for maintenance. Enhanced instrumentation is provided to enable improved diagnostics and prognostics, measurable safety integrity levels, and reduced human errors in pull/no pull decisions.
This approach has been applied to the development of advanced BOP control systems that include innovative design features to reduce downtime and enhance safety for deepwater drilling. The approach focuses on development of advanced instrumentation and decision support for continuous assessment of BOP health, assessment of compliance to regulatory and industry standards for BOP functions, automatic reconfiguration to compensate for component failures, and determination whether operations can continue or if the BOP must be pulled for maintenance.