bluuebunny/crossref_metadata_2025_split huggingface dataset:
Aasta Hansteen Spar Inshore Pre-Service Operations
Authors: Edelson David , Jegannathan Manoj , Harris Tyler , Theckumpurath Basil , Selstad Henning , Krokeide Bjorn , Person Morten 
Published: April 2019

Abstract
This paper presents the overview of the Pre-Service operations for the Aasta Hansteen field development. The paper also covers the execution challenges, supporting engineering and procedures followed for the various activities.
The Aasta Hansteen Field development at a water depth of 1300m is the deepest field on the Norwegian Continental Shelf (NCS). The field is remotely located north of the Arctic Circle, in a particularly harsh environment 300km off the coast of Northern Norway, with 140km to the closest offshore installation.
In the past, the pre-service marine operations for Spar platforms were completed at the offshore field locations. The Aasta Hansteen development presented the opportunity to complete the entire pre-service operations in the sheltered waters of the deep Norwegian fjords, making it a unique, first-of-a-kind inshore pre-service operations for a Spar platform ever executed. This advantage also helped to significantly reduce the cost and complexity of the pre-service operations effort for the project.
There were several firsts in the industry for the Aasta Hansteen Spar platform, namely; Largest and heaviest Spar delivered, First Spar in Norwegian waters and subject to Norwegian rules, first full pre-service scope inshore in a fjord, first requirement for Structural Tank Inspection on a Spar Hull, first requirement for a Submergence Test, largest topside catamaran mating at 22,500 Te. Many of these firsts heavily influenced the planning and execution of the Pre-Service Operations for this project. The significance of these are also highlighted in this paper.
Smart Integration of Natural Gas Valorization Systems and Flexible Plant Installation in Existing and Low Capacity Gas Production Sites
Authors: Falsini Matteo , Conforti Filippo 
Published: April 2019

Abstract
The increasing demand of energy efficiency, the evolution of emission regulatory and the limited investments allocation, increases the attractiveness for flexible gas valorization systems [GGFR]. Gas valorization system can be considered all the technical solution i.e process or new equipment installation that allow to use wasted gas sources to produce electricity of mechanical power for different application.
The recovery of associated or stranded gases presents various complexities especially if applied to remote locations. For this reason, to maximize synergies with the existing premises, a flexible design and pre-assembled solutions might be recommended.
This paper presents, the integration of flexible installation solutions with natural gas valorization systems. This approach is finalized to maximize the production capability of a hydrocarbon production site with a low impact on existing infrastructures and relocation possibility.
On this regard, the main emphasis is placed to the following actions: The integration of flexible systems in the gas recovery processes,The upgrade of existing equipment to resolve production bottleneck,The use of mobile technology to accommodate plant flexibility.
During the plant life cycle, operating conditions of some critical links of the production chain need to to be adjusted. In this case the upgrades of processes and equipment flexibility helps to prevent inefficiencies that may result in gas flow underutilization or associated gas flaring.
Moderate natural gas flows, either from oil production associated products or stranded gas reserves, limits the economic viability of a gas valorization system. For this reason, solutions integrating the standard design balance of plant and the mobile truck architecture are technical choice that provide beneficial impact on the site effectiveness and economics. Moreover, mobile plants provide the further advantage to be reused in different sites through a simple relocation and minor adjustment.
Offshore oil plants may not include gas boosting/offload or spare power generation solutions while small space and limited load capability generate additional complexities. In these cases, a dedicated approach like the construction of floating modular systems to be connected to the existing structure represent a viable solution.
Demonstrating the Feasibility of New-Build Hull-Platform for FPSO in Various Oil Field
Authors: Sogawa Yasuhiro , Tanaka Shigeru 
Published: April 2019

AbstractIt is a challenging problem to achieve low cost and fast-track construction for new-build FPSO hulls. In order to cope with this problem, the authors developed and reported unique modular design and multi-yard construction concept, "noah-FPSO Hull" [1][2][3]. After that, the authors continued to improve its design and expanded its flexibility for harsh environment and customer's requests. As a result, new standardized fore/aft modules and cargo tank module have been developed to expand the flexibility. This paper presents the design of the newly developed modules and the feasibility for harsh environment.
Application of the Findings of the PISA Joint Industry Project in the Design of Monopile Foundations for a North Sea Wind Farm
Authors: Manceau Sebastien , McLean Robert , Sia Anna , Soares Marisa 
Published: April 2019

Abstract
Monopiles are the most common foundation type in the offshore wind industry. Their design is largely dependent on the ability to accurately model the soil-structure response of the foundation, with more refined modelling approaches enabling significant reductions in required embedment depth, fabrication cost and installation risk. The PISA joint industry project (JIP) has been completed in recent years with the objectives of developing a more refined soil-structure response modelling method compared to other available methods such as the API p-y curve approach. The scope of this paper is to detail how the PISA recommendations have been implemented on a real offshore wind farm project located in the UK North Sea, identifying how the findings can be incorporated into a combined geotechnical and structural analysis approach to enable efficient serial design of multiple foundations for wind turbines.
The paper presents how existing design processes and criteria can be modified to take into account the recommendations of the PISA JIP for use in design. Discussion will be provided on the following procedures: calibration of the PISA 1-D soil response formulations to site specific conditions; the combination of the homogeneous sand and clay formulations to accurately model soil-structure response in layered soil profiles; and, consideration of the effects of cyclic loading in conjunction with the use of the PISA monotonic soil response formulations.
Results will be presented to demonstrate the calibration of the PISA 1-D soil response formulations to a layered soil site. Discussion will also be provided on the significant monopile lengths savings achieved when using a PISA approach compared to an API p-y curve approach. The monopile mass reduction will be illustrated against trends derived from installed monopiles. Observations will be provided on how the use of a PISA based approach can affect the governing design cases and how this is likely to impact on monopile design for future projects. Discussions and conclusions will also be presented on the challenges of implementing the PISA recommendations in monopile design for real projects and what additional work is required to enable further costs savings in implementing the new design approach.
The PISA JIP recommendations are the cutting edge in monopile foundation design. The paper will provide discussion on how these recommendations can be effectively implemented in design based on experience from the foundation design for a real offshore wind farm. The wind farm in question will be one of the first constructed for which foundations have been designed using a PISA based method, demonstrating the significant CAPEX savings possible using the PISA approach.
Extracting Value from Data Using an Industrial Data Platform to Provide a Foundational Digital Twin
Authors: Laborie Francois , Røed Ole Christian , Engdahl Geir , Camp Audrey 
Published: April 2019

Abstract
Oil & Gas data currently exists within a world of data silos. Lack of data is not the challenge. A wide variety of data is collected, including sensor values, P&IDs, ERP, and depth-based trajectories. Rather, the challenge pertains to data usefulness. The root of the problem is a combination of factors, including poor data infrastructure, incompatible operational data systems, and restricted data access. All this translates to a low maturity of digitalization across the Oil & Gas industry. To date, digitalization efforts have been limited to pilot projects, proofs of concept and case studies, with no large-scale operationalized projects.
Aker BP, one of Europe's largest independent Oil & Gas companies, has broken through the typical roadblocks by deploying an industrial data platform across all five of its operational assets. The platform aggregates and processes data from sensors and contextualizes it, structuring it in relation to process diagrams, production information, 3D-models, and event data (maintenance, incidents). Everything linked in the real world is also linked in the platform. This has dramatically reduced the cost of integration and maintenance, while simultaneously enabling scalability, speed of development, and data openness throughout the Aker BP organization. The data platform handles live and historical data for close to 200,000 sensors, with a peak transfer of 800,000 data points per second. Internal and external experts are able to apply state-of-the-art algorithms to visualize and solve critical business problems. A range of third-party applications and data scientists also use the 1+ trillion data points in the platform to create value and support Aker BP's strategy for day-to-day operations and long-term digital transformation.
To realize the promise of digitalization, unlocking the value of data must be made a priority within the Oil & Gas industry. This paper will describe the implementation of the industrial data platform, explaining how data streamed from many, disparate, underlying systems is contextualized in the data platform to provide a holistic view of all processes and operations, thus creating a foundational digital twin for each asset, ready to empower machine learning applications for optimization and automatization, as well as human-facing applications, such as advanced visualizations and apps for the digital field worker.
Feasibility Analysis on Using a Group of Wind Turbines as a Hub to Supply Electricity to Offshore Oil and Gas Platforms in the Gulf of Mexico
Authors: Haces-Fernandez Francisco , Li Hua , Ramirez David 
Published: April 2019

Abstract
Previous research indicated that interconnecting offshore platforms in the Gulf of Mexico with wind energy and the onshore grid can provide significant advantages. This research considered groups of offshore wind turbines as energy hubs to provide electricity to nearby offshore platforms, including the evaluation of energy deficits caused by wind wakes. The proposed research idea allows platforms to improve energy efficiency, save fuel, reduce air pollution, and increase income by selling surplus energy. The energy output of these wind turbines was estimated considering wake effects. Diverse layouts were modeled applying meteorological and geographical data integrated with wind wake models to solve a realistic wind farm layout optimization problem. The research created a methodology to optimize a group of offshore wind turbines performance in the Gulf of Mexico, minimizing negative interference while maximizing power output. Results indicated that an important number of locations of offshore oil and gas platforms were able to provide adequate levels of wind energy. Variable wind directions cause changes on the behavior of the turbulent wakes. Therefore, the layout of wind turbines needs to be optimized to minimize negative interaction while maximizing power output under different wind conditions. Furthermore, the analysis revealed the feasibility of installing, in particular optimal locations, wind farms that would simultaneously serve several offshore platforms in close proximity (as hubs) while the system remains connected to the onshore grid.
Forensic Data & Decisions: Utilizing Data Intended for Other Purposes
Authors: Wisch David , Huyse Luc 
Published: April 2019

During installation of the Big Foot TLP, nine of the 16 pre-installed tendons fell to the seafloor prior to completion of installation. a comprehensive Root Cause Analysis was undertaken to determine the "cause" of the incident. During the early investigative phase, a number of sources of data were identified. Two particular information sets were gathered, interrogated, processed, etc. to extract usable patterns and values to aid in decision making. A third composite data set of deepwater current values was coupled to extract additional insights. All data sets were designed for installation support and not intended for a forensic investigation. Identification of the data, understanding original intent, multi-stage filtering and conclusions will be illustrated.
One is a time series containing x, y, z spatial data of a common location on each of the 16 pre-installed tendon assemblies and the second being non-periodic discrete air volume measurements of buoyancy devices. The time series data contained repetitive data points, contained spurious readings, etc. The multi-stage automatic and manual filtering processes utilized to develop non-periodic traces useful for insight and decision making is described. Accompanying this discussion will be the description of original intent and the adaptation from intended use to RCA value. The second data involved non-periodic air volume measurements. Initial interpretation of data during installation was sufficient for operational purposes. A Root Cause Analysis team analyzed the data including use of correlative time series unrelated to the measurement to identify telling patterns useful in decisions.
The absolute as recorded data was unable to provide sufficient confidence using standard data processing techniques. Target manual filtering and correlative comparisons provided useful and valuable decision-making insights. The ability to use data designed for specific purposes not aligned with ultimate usage for RCA purposes is shown
The Art of Disintegration – Ten Years in Review of Disintegrable Metals and Downhole Tools
Authors: Xu Zhiyue , Zhang Zhihue 
Published: April 2019

Disintegrable metal (DM) has proven its market value since the first set of disintegrable frac balls were successfully employed in a shale well in Bakken field about 10 years ago. The DM material technology and tools have changed the downhole tool operation landscape with unprecedented efficiency, reliability, by reducing the operational complexity or simplifying tool installation or actuation procedures. This paper reviews the advancement of DM materials technology, arts to engineer and control the disintegrating performance, various DM downhole tools, and the field operation case studies over the last 10 years.
Review of the art of disintegration of disintegrable metals is based literature surveys and author’s own research and development results. Disintegrable metals currently available on the market could be classified into two different metallic systems based on their base metal chemistry: magnesium based disintegrable metal and aluminum-based disintegrable metal. Both systems are light weight, strong as steel and completely disintegrable in typical downhole environments. The paper will review the material design, microstructure, and properties of the two metallic systems, then discuss how to match material properties with requirement of downhole disintegrable tools, and finally share field operation cases.
Most of DM materials have micro-galvanic cells built into their microstructures and disintegrate through galvanic corrosion when contacting with wellbore fluid. Key variables affecting the rate of disintegration include material composition, well temperature, tool surface area exposure to a fluid, fluid type, concentration and agitation conditions. The review reveals that it is critical to select the correct DM material to match the application environment for a successful field application of disintegrable tool. In today’s multi-stage hydraulic fracturing market, DM tools would be the preferred technology of choice when DM material selection and tool design and performance match properly to the needs of hytraulic fracture operation of a well.
The thermodynamics and kinetics that control the disintegration performance of DM tools, or the art of disintegration, will be reviewed and shared with the readers. The profound arts and engineering of DM materials and field case studies shared by this paper would shed light on how to make sound selection of DM materials, design optimal DM tools for a defined well or field application, develop the best field operation procedures, and execute a MD application efficiently.
Aasta Hansteen Spar and Topside Fabrication
Authors: Kim Dong Hyub , Seberg Lars Cato , Witsøe Stig Arne 
Published: April 2019

Abstract
This paper describes the fabrication of the world' largest and most complex Truss Spar Platform, Aasta Hansteen, built for the Norwegian Continental Shelf (NCS) to be operated by Equinor. It was built according to NORSOK standard, Norwegian governing laws and regulations and other Company requirements.
Hyundai Heavy Industries (HHI) was awarded an EPC Contract (Engineering, Procurement, and Construction) for the Topside of Spar Platform, and HHI and TechnipFMC formed a Consortium responsible for the overall delivery of the Spar Hull. TechnipFMC was responsible for the design, engineering and equipment procurement, whereas HHI was responsible for Fabrication and delivery.
This paper addresses the characteristics of the design of Aasta Hansteen Spar Platform and highlights critical aspects of the Construction Method of Spar Hull at HHI's offshore yard in Ulsan, Korea.
Shallow Water Testing of 9 - 12 MVA Variable Speed Drive for Subsea Installation
Authors: Lendenmann Heinz , Laneryd Tor , Virtanen Esa , Cagienard Raphael , Wagner Thomas , Missing Kim 
Published: April 2019

Abstract
The electrical Variable Speed Drive (VSD) system presented is designed for installation on the sea floor to drive nearby electric motors for pumps and gas compressors. A modular concept of the VSD is developed and intended to operate a wide range of subsea motors of powers from 0.5 to 18 MVA, with voltages from 2.0 kV to 7.2 kV or more, and fundamental frequencies up to 300 Hz. Step-out distances from a few km to over 600 km can be accommodated.
The pressure compensated design effectively removes limits as to the depth of deployment. Pressure compensation is achieved by submerging the drive hardware including the drive transformer in a dielectric liquid which also acts as coolant. The electric power components, including capacitors, semiconductors, and the control electronics are designed with increased margins and redundant hardware, pressure resistance, and materials chosen for compatibility with the dielectric liquid, to achieve a highly reliable design of the overall VSD.
The drive was deployed into shallow water in a harbor in Vaasa Finland for testing. A top side station was built implementing a "Power-In-the-Loop" approach, where the VSD output energy is recovered back into the drive input such that the grid supply only provides the lost power, but not the much higher circulated power.
The drive operated more than 1000 h at 22 kV input and 6.9 - 7.2 kV output voltage at different power levels. We conclude from this first shallow water test, that all components of the VSD system work properly together up to 1000 A output current. Different operation conditions reflecting the envisioned application, including redundancy capability were successfully tested. The thermal performance was extensively verified, including an optional external heat exchanger to achieve high ratings even in warm waters.
To our knowledge this is the first time a medium voltage drive is operated at 9 to 12 MVA for an extended time submerged in a sea water environment. All its modules are designed to operate down to depths of 10’000 ft / 3000 m or more and are concluding qualification according to API17F and SEPS 1002.
Biodegradable Anti-Agglomerant Chemistry for Hydrate Plug Prevention in Various Production Conditions
Authors: Monteiro Deepak Steven , Vo Loan Kim , Prince Philippe , Bodnar Scot Harris 
Published: April 2019

Abstract
Performance of anti-agglomerants (AAs) depends on many factors, including salinity, water cut (WC), characteristics of the hydrocarbons, gas composition, reservoir conditions, production system conditions, and especially AA stability at the application conditions. Most AAs are surfactants, with one or multiple long hydrophobic tails and a charged hydrophilic head. This class of chemistry is often not easily degraded in the environment and can, therefore, be eliminated from consideration for application in environmentally sensitive regions. This paper presents the development of an AA that can be applied under a wide range of production conditions and is unique because of its ready biodegradability [&gt;60% compared to other AAs, which either are not biodegradable (&lt;20%) or can only achieve inherent biodegradability of 20 to 60%].
Rocking cell testing was conducted to determine the performance boundaries of the AA chemistry. Light, medium, and dark oils from various fields were used to evaluate the performance of the AA in aqueous phases ranging from condensed water (effectively, 0% salinity) to high salinity (~12%). Test results were categorized as "pass" for transportable hydrate slurries and "fail" if the systems plugged, and/or showed large hydrate crystals, and/or resulted in high slurry viscosity. Visual observations throughout the test and proximity sensor data provided qualitative and quantitative representations of the behavior of fluids in each cell. Water quality and emulsion tendency testing were conducted to verify that the AA would be suitable for offshore use and operable at topside. Biodegradation testing of the AA was conducted in seawater according to OECD 306 (1992).
Systematic study demonstrated strong versatility for application of this AA to help prevent hydrate blockages in pipelines. Optimizing the head and tail length of the molecule was crucial for allowing it to treat a wide range of salinities, WCs, and oils with different API gravities. No sign of hydrate blockage was observed when applying the designed AA at minimum effective dosage (MED). The optimized product demonstrates overboard oil and water quality, thereby eliminating the need for an emulsion breaker and/or a water clarifier. The presented AA has a ready biodegradability of 61.8% [greater than 60% is categorized as readily biodegradable using OECD 306 (1992) methodology] and has been successfully implemented to treat hydrate plugging in the Gulf of Mexico (GOM).