bluuebunny/crossref_metadata_2025_split huggingface dataset:
Onde está o vírus? Manipulação política da linguagem sobre o coronavírus
Authors: Moura Heronides 
Published: August 2021

Neste artigo, tento mostrar que alguns discursos políticos radicais, seja de direita ou de esquerda, manipulam a linguagem sobre o coronavírus, com o objetivo de justificar afirmações enviesadas e sem evidências sobre a pandemia da Covid-19. Este tipo de manipulação está em conformidade com a percepção de que a manipulação política da linguagem se baseia numa fusão de verdades parciais e de mentiras completas (Katukani, 2018). Os dados foram coletados no site de notícias brasileiro de extrema-direita criticanacional.com.br e no livro Vírus soberano?, escrito pela filósofa pós-moderna e de esquerda Donatella di Cesare. A análise dos dados mostra que a manipulação mais importante encontrada nestes discursos políticos é a ocultação de informação relevante sobre a localização do vírus. A grande maioria das sentenças sobre vírus encontradas no corpus não oferece nenhuma indicação sobre a localização do vírus e sobre sua propagação. Será mostrado que esta ocultação favorece as informações infundadas que são propagadas pelos dois discursos políticos radicais analisados neste artigo. A fim de estabelecer uma comparação com os resultados dessas análises, foram também coletados dados no jornal Folha de São Paulo. A conclusão é que as sentenças deste corpus jornalístico são muito mais precisas em relação à localização do vírus.
Palavras-chave: Coronavírus; Manipulação Política; Linguagem.
Automation of Large Parametric Flow Assurance Analyses in the Cloud
Authors: Hubbard Rex Sinclair , Staaden Leon Geoffrey , Scales Derek John , Tran Andrew Chin Foong 
Published: August 2021

Abstract
The objective of this study was to determine the highest flowrate through a client's existing flowline without top-of-line condensation rates exceeding a critical value of 0.25 g/m2.s. Automation of the workflow allowed a large combination of operating conditions to be analysed within a shorter timeframe than a traditional flow assurance analysis process.
A multiparameter case matrix was developed to analyse the full range of process and environmental variables. A proprietary multiphase flow assurance software in the cloud was used to develop a reference case model. Then a software script was developed to read in the reference case model's code and produce input files for 1,080 cases. All cases were run within 30 minutes in the cloud. Another software script then extracted key data from the 1,080 output files into a single Excel spreadsheet to enable data visualisation and identification of a simple and effective flow rate criterion to limit condensation rates.
Automation of the workflow allowed all combinations of variables to be analysed within a shorter timeframe compared to the traditional flow assurance analysis process, which usually analyses a somewhat limited number of suspected worst-case scenarios selected based on engineering judgement.
The bulk data resulting from the automated workflow enabled a single integrity limit criterion to be applied with a high level of confidence, namely the fluid temperature measured at a subsea corrosion probe. This simplified integrity limit allows the operators to easily maximise production for any combination of process and environmental conditions, whilst maintaining confidence that they are not exceeding the critical condensation rate.
Wellhead Movement Analysis and Surface Casing Integrity in Pre-Salt Wells
Authors: Cutrim Fabio Sawada , De Souza Charlton Okama , De Souza Bruno Sergio Pimentel 
Published: August 2021

AbstractAs a general practice in the oil and gas industry, the well foundation, composed by the conductor and the surface casing, is designed with a strict tolerance regarding cement shortfall on the surface casing. However, in a pre-salt scenario, in order to reduce the costs of well construction, the surface casing shoe generally reaches the top of salt. In this case, it is quite hard to make the cement job reach the mudline due to problems like salt dissolution (generating high calipers) and presence of many geological faults in the post-salt zone (which can work as a lost circulation area). Besides that, an evaluation of the wellhead movement is necessary so that the structural restrictions of subsea equipment connected to the wellhead are not violated.This work had the goal of presenting a coupled structural model to analyze the foundation of a subsea well with a partially cemented surface casing, where the safety factors of surface casing are evaluated in the whole well life cycle along with the wellhead movement due to the loads related to each step of this cycle. A sensitivity analysis on the top of cement (measured from the casing shoe) is made, varying it from 300 m to 800 m.The results showed wellhead movement consistent with what is observed in the field, once no axial movement has been reported. Additionally, it was highlighted that the foundation design depends on the operations during the well construction and its future purpose, production or injection, because the thermal loads associated with operations have different impacts.
Optimization Applied to Buzios Flexible Riser Systems and Subsea Layout
Authors: Gasparetto Vinicius , Hernalsteens Thierry , Britto Joao Francisco Fleck Heck , Leao Joab Flavio Araujo , Dos Santos Thiago Duarte Fonseca , De Oliveira Ricardo Caldeira 
Published: August 2021

AbstractBuzios is a super-giant ultra-deep-water pre-salt oil and gas field located in the Santos Basin off Brazil's Southeastern coast. There are four production systems already installed in the field. Designed to use flexible pipes to tie back the production and injection wells to the FPSOs (Floating Production Storage and Offloading), these systems have taken advantage from several lessons learned in the previous projects installed by Petrobras in Santos Basin pre-salt areas since 2010. This knowledge, combined with advances in flexible pipe technology, use of long-term contracts and early engagement with suppliers, made it possible to optimize the field development, minimizing the risks and reducing the capital expenditure (CAPEX) initially planned.This paper presents the first four Buzios subsea system developments, highlighting some of the technological achievements applied in the field, as the first wide application of 8" Internal Diameter (ID) flexible production pipes for ultra-deep water, leading to faster ramp-ups and higher production flowrates. It describes how the supply chain strategy provided flexibility to cover the remaining project uncertainties, and reports the optimizations carried out in flexible riser systems and subsea layouts.The flexible risers, usually installed in lazy wave configurations at such water depths, were optimized reducing the total buoyancy necessary. For water injection and service lines, the buoyancy modules were completely removed, and thus the lines were installed in a free-hanging configuration. Riser configuration optimizations promoted a drop of around 25% on total riser CAPEX and allowed the riser anchor position to be placed closer to the floating production unit, promoting opportunities for reducing the subsea tieback lengths. Standardization of pipe specifications and the riser configurations allowed the projects to exchange the lines, increasing flexibility and avoiding riser interference in a scenario with multiple suppliers.Furthermore, Buzios was the first ultra-deep-water project to install a flexible line, riser, and flowline, with fully Controlled Annulus Solution (CAS). This system, developed by TechnipFMC, allows pipe integrity management from the topside, which reduces subsea inspections.As an outcome of the technological improvements and the optimizations applied to the Buzios subsea system, a vast reduction in subsea CAPEX it was achieved, with a swift production ramp-up.
Guyana Operations and First Oil
Authors: Ryan Mike F. , Unietis Brian , Kaverzin Alexander , Townson Travys , Steves James , Chew Celine , Maggard Mark , Jones Justin , McGehee Brendan R. , Minnaar Karel 
Published: August 2021

AbstractThe Liza Phase 1 development project features the Liza Destiny Floating Production, Storage, and Offloading (FPSO) vessel, moored 190 km offshore Guyana in 1,743 m (5,719 ft) of water, and four subsea drill centers supporting 17 wells. Not only was this a Greenfield development that required an integrated team to prepare for Operations; it was also located in a New Frontier that required development of logistics and marine infrastructure to support multi drillship and FPSO operations in challenging metocean and tidal conditions. In addition, early operations and production testing was further complicated by the COVID-19 pandemic and safety protocols put in place to keep the workforce safe.Three aspects of achieving First Oil are discussed, highlighting challenges and lessons learned:Managing subsea completions, well cleanup, and flow assurance while drilling was ongoing Enabling accurate data collection from Multi-Phase Flow Meters (MPFMs) and downhole pressure gauges, which was critical to developing foundational understanding of well performance for reservoir characterization and management Establishing an integrated asset team and workflows to ensure life cycle value capture by managing complex marine operations, commissioning, and surveillance while meeting stringent COVID-19 protocolsLessons learned from Destiny Operations will be incorporated into future projects, including a robust digital strategy centered on a fiber ring to shore, which will enable high-speed communications for future FPSOs, and an onshore integrated operations control center for improvement of long-term operations. Early understanding of reservoir connectivity and performance from data collection will continue to inform the reservoir management strategy so as to maximize asset value for the country of Guyana.
Predictive Maintenance Using the Executable Digital Twin xDT
Authors: Goodheart Kevin , Mas Peter , Ismail Maged , Badiali Umberto , Hendicx Wim 
Published: August 2021

Abstract
Through the introduction of programmable logic controller (PLCs), Dynamic Process & Controls modeling, integrating with Multiphysics Mechatronics & 3D equipment simulation modeling, companies can work in the online real-time environment. This modeling of equipment or processes builds the foundation for digital transformation of subsea, topside, onshore and plant environments.
In the design and operation of field equipment, the physics based Digital Twin is getting more and more traction to develop virtually the equipment because of recent prediction accuracy improvement and faster calculation times. Such digital twins allow to find the optimal operating conditions and predictive maintenance schedules for operation.
In this timeslot we will explain, based on few industrial examples, a new set of capabilities that allow companies to get the maximum out of digital twins to be able to use them on their equipment. By applying a structured process using Digital Twins to be able to convert the existing knowledge & data at Companies into solution to be more predictive on their equipment. This will deliver substantial return on investment (ROI) for the Oil and Gas Industry.
An AI based methodology to perform Model Order Reduction on the digital twin to be able to get real time response in connection to online unit information An AI based methodology to convert the reduced model into a virtual sensor for online quality predictions or predictive maintenance scheduling as well as to use it for creating an optimal controller of the unit based on the product requirements Fast edge computing hardware that can collect data from sensors and, in real time, run the Executable Digital Twin (xDT) and suggest corrective action to the operator or run in closed loop control
PEKK Poly Ether Ketone Ketone for High Temperature High Pressure Oil & Gas Conditions
Authors: Geslin Alexis , Paul Clément , Bussi Philippe , Barsotti Robert , Hollahan Jonathon , Calvin Mary 
Published: August 2021

Abstract
Poly Aryl Ether Ketones (PAEK), and in particular Poly Ether Ether Ketone (PEEK), have established themselves as polymers of choice for extreme environments. This is especially true in the Oil & Gas industry, with its very harsh conditions (high temperatures, high pressures and corrosive fluids). Within the PAEK family, Poly Ether Ketone (PEK) and Poly Ether Ketone Ether Ketone Ketone (PEKEKK) were later introduced to address the need for higher mechanical and thermal properties than PEEK; unfortunately, their chemical resistance has been reported as not matching that of PEEK.
In this paper, we report on novel, high viscosity, Poly Ether Ketone Ketone (PEKK) polymers that combine PEEK-like processing, high mechanical performances, barrier properties and very good chemical resistance in the NORSOK M710 test, positioning PEKK as a strong candidate for demanding Oil & Gas applications, such as O-rings, seals or electrical connectors.
Delivering Low Cost Wells at Matured Field with Enhanced Statistical Approach
Authors: Mhd Yusof M Hatta , Sulaiman M Zarkashi , A. Halim Rahimah , Ahmad Fauzi Nurfaridah , Sella Thurai Ahgheelan , Mahictin Masseera , Tg Yahya Tg Zuhaili , Muslim Fadli Adlan 
Published: August 2021

Abstract
This paper discusses the Case study of Field A in offshore Sarawak, Malaysia which focus on re-thinking development based on statistical analysis of the fields. Conventionally, well design is driven by subsurface requirement by targeting the high-reserve sand and well is designed to meet subsurface objectives. However, the conventional way may not be efficient to develop matured field environment due to the high CAPEX and the inconsistencies among well design especially in current volatile oil price period. The objective of this fit-for-purpose approach which is called "Cone Concept Statistical Approach" is to steer away from the conventional way of targeting only sweet spots whilst leaving the remaining potential resources undeveloped. Based on the statistical analysis and subsurface fields pattern, the "Cone Concept Statistical Approach" in which standardizing well design and trajectories was developed to extract the whole fields’ reserve at maximum. Well design boundaries were introduced to ensure this approach can be replicated throughout the field. Not only this study covers drilling perspective, completion perspective was also taken into consideration by exploring a cheaper and fit for purpose sand control method, considering it is a matured field with relatively short remaining field life. The Well Cost Catalogue for this field-specific was also developed which contains different types of design and completion, in order to holistically evaluate sand control method and identify the best option for the project moving forward.
This "Cone Concept Statistical Approach" aims to enable operator to drill more simple wells within the same allocated budget in which poses low-to-none risk in the design and execution phase, promoting learning curve to improve operation & HSE, and ultimately to get positive project economics. Since this simple approach can be implemented early on even during the pre-FEL stage, the FDP team & host authority can come together to jointly discuss the targets/platform ranking and segregate them into various phases. Hence, the number of platforms or drilling centers, and its location also can be optimized early on with this concept, and again, translating into further reduction in overall project cost. This paper will help other operators and host authority to understand better on how a specific development concept on statistical approach can result and turn the matured-challenging fields into more economically attractive projects – low overall development cost and maximizing the recovery.
Decommissioning Offshore Structures by Extraction of Foundation Mono piles Applying a Vibratory Hammer
Authors: van Dorp Rob , Middendorp Peter , Bielefeld Marcel , Verbeek Gerald 
Published: August 2021

Abstract
The vibratory hammer is one of the tools for the extraction of offshore foundation piles as well as monopiles for the decommissioning of offshore structures. In addition to the standard application, where a pile is driven downward to be installed, a vibratory hammer can also be applied to extract piles. For an efficient and commercially attractive application of vibratory hammers for this purpose, the extraction process needs to be modeled during the planning phase to ensure that the appropriate equipment is used. This paper describes how pile driving simulation software can be used to model the extraction process. This is further illustrated through a case study covering the extraction phase of the 1st (onshore) and 2nd (offshore) part of the Delft Offshore Turbine Project. A monopile with a diameter of 4.0 m was extracted approximate 6 months after installation onshore and then extracted several times offshore shortly after installation in the 2nd phase. The paper will not only present the actual extraction predictions, but also the monitoring data obtained during extraction and the results of the post-analysis.
Novel THOR Technology for Orientation of Vertical XT to Completions
Authors: Katsounas Nicholas Paul , Pathak Parth Dilip , Quates Daniel Ronald , Mosscrop Guy 
Published: August 2021

Abstract
On conventional vertical trees (VXTs) with a tubing hanger (TH) in the wellhead (WH), orientation of the VXT to the TH system is a complicated and expensive process. Leveraging patented technology, the tree to hanger orientation ring (THOR) and tooling were implemented to save CAPEX and OPEX while eliminating risks associated with conventional orientation solutions. An open-water tool installs an external alignment feature onto the wellhead, which is oriented with the tubing hanger already installed in the wellhead. The VXT then orients onto the wellhead with the help of this external alignment feature, resulting in correct orientation with the tubing hanger. This paper discusses the novel technology and its successful development and installation for a subsea project, which revolutionizes the VXT portfolio.
Rapid development of THOR technology was required along with expedient project execution. Utilizing digital-twin design techniques such as finite element analysis and operator simulations, the operating life of THOR tooling was investigated in parallel with project engineering. The novel nature of the THOR required unconventional testing, which was performed in-house. Project execution plan was implemented for engineering and manufacturing to successfully build the production equipment on schedule. Comprehensive system integration testing was completed upon the first attempt. The system was deployed to staging facilities before being delivered offshore to the customer and installed subsea in stages during April 2020. Involvement of the operators and installation contractors during the development stage made THOR's first deployment attempt a major success with zero recorded nonproductive time, even during COVID-19.
THOR technology reduces the number of components as well as the weight and size of the equipment. The novel THOR equipment can be run by a light intervention vessel rather than conventional equipment, which requires mobile offshore drilling units. The time spent to deploy the VXT system is also reduced, minimizing indirect supply-chain and field-service-related carbon emissions. This further enables reduced carbon emissions and overall carbon footprint of the entire project.
The field-proven THOR technology is an evolutionary orientation technology that simplifies the installation operations for the vertical tree and tubing hanger. This technology maintains the robust conventional system configuration post installation and hence does not affect reliability of the VXT system.
Searay Autonomous Offshore Power System AOPS: Results of Sea Trials and Payload Support Demonstration
Authors: Lesemann Arvid Reenstjerna , Hammagren Erik Joel 
Published: August 2021

As the offshore energy sector looks to fully implement resident, autonomous, robotic, digital systems offshore, one missing piece of the puzzle is remote power generation. Further complicating these efforts are the owner/operators’ move towards net zero operations. The combination represents a significant dilemma for the offshore energy industry: if gensets and topside vessels are not appropriate or practical power sources for future resident systems, how will these needed cost and carbon-saving innovations come to market and get deployed in the field?

Objectives/Scope
The proposed paper will provide an overview of a new platform solution, an autonomous offshore power system (AOPS), that looks to complete the puzzle. A number of AOPS’ are under development world-wide. The paper will review the state-of-the-art, including the SeaRAY AOPS, which will undergo sea trials off the coast of Marine Corp Base Hawaii, on Oahu, Hawaii, USA. The sea trials are expected to last for six months.
Note: Because of COVID-related delays, the sea trials originally planned for late 2020 will now start in 2Q21. The August presentation at OTC will include the latest information available on the sea trials and co-deployed payload testing.

Methods, Procedures, Process
The SeaRAY AOPS is the result of a project co-sponsored by the U.S. Department of Energy, U.S. Navy, and C·Power, to design, build, and test a novel AOPS technology. The SeaRAY AOPS provides kW-scale power generation, energy storage, and real-time data and communications capabilities for remote, offshore systems, including unmanned subsea and surface vehicles (e.g., AUVs, ROVs, USVs), sensor payloads (e.g., environmental monitoring or methane emissions) and operating equipment (e.g., emergency power for failed/failing umbilical, field modernization, or redundant power for BOP systems).
Satisfying the need for cleaner operations, the SeaRAY and other AOPS devices capture and convert ocean energy into electricity to charge the energy storage system. The payloads, in turn, receive their power from the intermediate energy storage system, allowing campaign-based or extended residency.

Results, Observations, Conclusions
The paper will review the initial results from the planning, permitting, deployment, operation, and maintenance of the SeaRAY AOPS and the co-deployed sensor and vehicle payloads, which include a seafloor acoustical environmental monitoring system and a hybrid AUV.
Novel/Additive Information: The market impact of AOPS’ for the offshore energy industry can be significant, as the class of systems is intended to enable reductions in operational costs, carbon emissions, and complexity, while enabling a fuller implementation of autonomous and semi-autonomous resident systems. The paper will outline these features and benefits for the offshore energy industry, along with the results to-date of the novel SeaRAY AOPS’ sea trials.