bluuebunny/crossref_metadata_2025 huggingface dataset:
FPSO Value Creation Portfolio Conception and Management
Authors: Brochado M. C. , Nascimento C. A. M. , Melo M. V. , Cervo R. F. C. , Manoel R. P.
Published: April 2024

In the beginning of 2021, Petrobras created its future vision for floating production storage and offloading (FPSO) projects and decided to create a value creation program based in the following aspects: build an interdepartmental effort (Engineering, Research & Development [R&D], and Operation), with a strategic approach through key topics, channeling resources to add value to our projects. Besides, the idea was to concentrate the innovation pipeline in a single governance, creating a discussion forum apart from projects schedule (conceptual and front-end engineering design [FEED] development). The challenges related to future projects were mapped and objectives and key performance indicators (KPIs) were defined: increase net present value (NPV) of FPSO projects and reduce human exposure to risk and greenhouse gas (GHG) emissions.

The program, currently called FPSO+, is based on a portfolio of optimization and innovation projects (incremental and disruptive) to evaluate improvements in the designs (concept and FEED phases) where key problems are mapped, and solutions are searched inside the project teams, R&D initiatives, supply chain and through industry benchmark. Challenges and the required solutions are evaluated considering an integrated future vision for FPSOs, where Engineering, R&D and Operation work together to optimize total lifecycle cost of ownership (TLCO), reduce emissions and reduce human risk exposure.

It was achieved a reduction around 16% in GHG emissions (kgCO2 e/boe, per new FPSO), 30% increase in NPV and approximately 4% reduction in man-hours exposed to risk (engineering, procurement, and construction [EPC] phase and offshore phase). These results are related to 2021 and 2022. The portfolio includes a variety of areas, from digital solutions to new processing concepts and from new coatings and non-metallic materials to design simplification. Management procedures were created for portfolio planning and execution, including a valuation guideline, new technologies risk assessment and KPIs for the teams involved. The valuation components (capital expenditure [CAPEX], operational expenditure [OPEX], GHG emissions, oil and gas production impacts) required a strategy to be obtained from solid technical data and reliable sources.
American Petroleum Institute Standards and Other Initiatives in Support of the Energy Transition
Authors: Watkins P. D. , Roueche J. N. , Miller D. L.
Published: April 2024

As the worldwide energy supply continues to diversify to meet growing demands and address climate goals, operators and other stakeholders in the natural gas and petroleum industry are pivoting to address these dual needs. This will require development, adoption, and deployment of innovative technologies in support of both traditional energy and emerging forms of lower-carbon energy. A foundational aspect of meeting these needs is the industry's use of standardization, and that, too, should be applied to implementation of these new technologies. The advancement of innovative technologies is foundational to American Petroleum Institute's (API) Climate Action Framework (CAF) initiative to accelerate technology to reduce emissions while meeting growing energy needs.

While API has several initiatives well underway in the form of funded research to help meet this challenge, API has also moved quickly to address emerging needs in the form of standards and other initiatives. These include the publications of:

API Technical Report 1533, Lubricants Life Cycle Assessment and Carbon Footprinting – Methodology and Best Practice, First Edition, May 2023; API Carbon Dioxide (CO2) Emergency Response Tactical Guidance Document: Guidelines for Preparedness and Initial Response to a Pipeline Release of Carbon Dioxide (CO2), August 2023, created with the Liquid Energy Pipeline Association (LEPA) and developed with input from the National Association of State Fire Marshals; and The development with the Offshore Operators Committee of API Recommended Practice 75W, Safety and Environmental Management System for Offshore Wind Operations and Assets, with the first edition anticipated mid-2024.

Of particular interest is that both the CO2 emergency response document and Recommended Practice 75W have involved working with both traditional and nontraditional partnering organizations, which could lead to broader acceptance and use.

Likewise, it is especially important in implementing these technologies and operations to engage non-traditional stakeholders to ensure robust consensus. API is leading the way on this critical issue as well with its Industry in Action: Focus on Environmental Justice report, published June 2023. This approach is embodied in API's CAF text that "Meeting this challenge requires new approaches, new partners, new policies and continuous innovation."
Well Design Process Supported by Artificial Intelligence
Authors: Junior Antonio Carlos Ramos , da Cunha Carolina Bertholdo , de Souza Santos Cristiano , dos Anjos Jorel Lopes Rodrigues , Marques Marcello , Leal Marcio Fernandes , da Fonseca Paulo Roberto Santos Pinto , da Cunha Pereira Pinto Rafael Gustavo , Oliveira Francisco Bráulio
Published: April 2024

In recent years, artificial intelligence (AI) has been changing the way the industry operates, especially the oil industry. In the oil exploration and production activity, specifically in the Reservoirs and Wells areas, the use of AI has been growing exponentially, with applications ranging from reservoir drainage plan evaluation (CARDOSO et al., 2017) to predicting well instability issues during drilling (LENWOUE et al., 2023).

The Selection of Alternatives via Artificial Intelligence – SAVIA, arises from the Internal Startups Program, an initiative of Petrobras' Digital Transformation that aims to enable innovations conceived by the employees themselves for value generation, maximizing results and reducing costs for the Company. Centro de Estudos Avançados do Recife (CESAR), as a digital innovation center, partners with Petrobras in the development of these projects to make the ideas feasible.

SAVIA emerges from the need to streamline and innovate the well conception process, known as SELEPOÇO, by improving the technological incorporation stage aligned with cost optimization expectations. AI proposes to well Designers alternatives of well configuration for a given investment project.

The Minimum Viable Product (MVP) of SAVIA was developed through the construction of a decision tree algorithm based on the accumulated knowledge of Petrobras' technicians and engineers, in the form of business rules implemented in Python, and the construction of a machine learning model based on historical data from built wells. Data from lithology and other information from about 1600 offshore wells built by Petrobras in the last two decades were used to train and assess SAVIA's performance.
Enhancing Energy Efficiency and Operability in Offshore Drilling Operations: Validation and Benefits of a Machine Learning-Based Vessel Motion Prediction Application
Authors: Canache D. A. Chique , Russo M. , Haakonsen R. , Stavland O. G. , Borsholm T.
Published: April 2024

This paper delves into the framework of a new vessel motion prediction application that leverages advanced machine learning (ML) techniques in conjunction with metocean forecasts to predict vessel motions as well as thruster loads. The paper illustrates the validation process, comparing predicted vessel motions and thruster utilization against actual records across several time intervals within a drilling campaign. The discussion encompasses the key role of diverse input factors in shaping prediction accuracy, and outlines strategies to address the inherent uncertainties associated with methods, weather forecasts, and the stochastic nature of the underlying problem.

Our innovative approach for vessel motion prediction forecasting employs physics-informed neural networks. These networks were trained using second-order time domain simulations, encompassing environmental variables like waves, wind, and current, along with a vessel dynamic positioning (DP) control system model. Our methodology marks a significant advancement in the field, offering a robust framework for efficiently developing performant motion prediction models grounded in the underlying physics.

The validation procedure yielded promising results, with the predicted responses trending well with the observed responses, and remaining near the expected range of responses attributed to machine learning model uncertainty and stochastic uncertainty innate to the marine environment. Discrepancies are noted and addressed with possible ways forward to improve the model.

Central to the paper's narrative is the exploration of the benefits stemming from the motion prediction application's implementation. The application's capacity to enhance operational and energy efficiency is highlighted in this paper. This work contributes to making sustainable drilling practices available by providing a tool predicting the future vessels response both in terms of motions and thruster loads which can be used to optimize the power plants efficiency while maintaining safe operations. This technology will contribute to bringing the industry closer to its objectives of reduced environmental impact.
The Twisting Effect on the Polyester Ropes during the Deep-Water Mooring Installation
Authors: Haach L. , Canedo J. , Tomazi A. , Duarte E.
Published: April 2024

Whilst the polyester rope is considered to be a matured technology that has been used as a mooring line in the offshore stationkeeping for more than 25 years, nowadays questions regarding synthetic rope constructions and its behavior still arise. One of these queries is related to the possible twisting that can be induced on the rope during the steps of mooring line installations. Although the recommendation of allowable twist can vary between manufacturers, the need to undo the twist to achieve those permitted twist levels could be a significant challenge. So the need to explore the behavior of synthetic ropes under those circumstances to refine the decision-making process is perceived. Industry experience states that the induced twist may affect the synthetic mooring rope performance, i.e., in general the breaking strength and fatigue life can be reduced due to the influence of torsion in the rope construction. However, even after many years, there is no sufficient data that provides the short and long-term impact of twisting spread over the rope. Eventually the questions that should be answered are: what twist level could be permitted without performance loss? What could be the impact regarding the rope performance if the twisting exceeds the recommended by the rope manufacturer? Different rope constructions might affect the twisting loss performance? As manufacturers, it is incumbent upon us to address these questions; otherwise, we will lack test evidence to guide installers in the face of practical situations that demand more than empirical experience during offshore mooring rope installations.
Digital Twin for Model Based Operational Support: Innovative Applications
Authors: Ogugbue C. E. , Greenawalt Z. , Kondratenko Y. , Dokun T. , Stewart C. , Cao F. , Hosein S. , Burbank W.
Published: April 2024

Within BP, network simulation and optimization are a well-established methodology for increasing and sustaining production capacity. To improve on existing workflows, BP has enhanced its previous petroleum/process engineering-focused toolkit and has globally deployed a production system digital twin end-to-end; Reservoir, Wells, Plant and Export, for model-based surveillance and optimization.

The production system digital twin is a cloud-based system that connects sensor data from each asset's data historian to an equipment data model and first principle steady state simulation tools to create a reliable status of the well network and processing facilities. This facilitates multi-disciplinary collaboration and is remotely accessible by global teams.

The integrated digital twin has three modes of operation: monitoring, simulation, and optimization. In monitoring mode, the models are automatically updated hourly with real-time data and key simulation results collected and saved. These monitoring simulations provide virtual sensor output via bespoke algorithms, revealing information that either real sensors cannot measure or are not installed to measure. Engineers utilize what-if simulation or optimization mode to test scenarios and explore capacity increase options or analyze optimization potential.

This paper will feature three practical applications to demonstrate realized values. It will describe elements of the integrated digital twin models deployed in BP's Gulf of Mexico assets, and outline the challenges and lessons in maintaining and auto-calibrating the digital twin.
Families of Robotic Systems Solving Offshore Wind Inspection Challenges
Authors: Brown S.
Published: April 2024

The AROWIND Project focuses on revolutionizing subsea inspections and monitoring of offshore wind farms using compact and easily deployable ROVs and AUVs/UUVs. Traditional methods are costly and time-consuming, often involving hiring dive teams, but by leveraging emerging technologies, inspections become cost-effective, quicker, and safer. The project aims to develop a USV-based subsea inspection system, integrating visual sensors, acoustic positioning, and 3D modeling capabilities. The concept of "systems of systems" involves collaboration among various robotics technologies, such as USVs deploying ROVs, aerial drones, and AUVs for diverse surveillance and inspection tasks. The success relies on software and firmware compatibility, mechanical integration, and advancements in autonomy, 3D visualization, and machine vision. The application extends beyond wind farms to underwater sediment cleaning, where ROVs provide a swift and precise solution, minimizing environmental impact while maximizing effectiveness.
Floating Offshore Wind Supply Chain Constraints and Opportunities
Authors: Kruger T. , Price S. , Wiedijk M.
Published: April 2024

Offshore wind power has become a priority in the United States because it has the potential to unlock substantial resources to deliver both economic and environmental benefits toward a net-zero emissions goal. Recent analysis suggests that up to 2,000 GW of offshore wind capacity will be needed by 2050 to keep global temperature increases below 1.5°C. At present, there is no offshore wind capacity in emerging markets other than China, and established energy markets like that of the United States have quite a way to go before offshore wind makes up a significant percentage of the energy mix. Changing the status quo is critical if the world is to meet ambitious targets for greenhouse gas (GHG) reductions and change needs to happen soon. "The long development timescales for offshore wind mean that efforts need to start now to ensure delivery of new capacity"1 (World Bank – Key Factors for Successful Development of Offshore Wind in Emerging Markets - 2021).

Creating a supply chain is a challenge, but it also is an opportunity because it presents the industry with a chance to take a holistic approach to building out capabilities from the ground up to deliver a healthy, diverse and sustainable supply chain that enables large-scale deployment and can support mass manufacturing and well-paying jobs for the years to come.

This paper analyzes multiple elements of the floating wind industry based on the experience of executing two operating floating wind projects and how this experience and these elements influence the formation of the supply chain system with special focus on the constraints and opportunities in developing a supply chain that is reliable and sustainable.

Focus areas include: Addressing uncertainty in the pipeline of projects by leveraging policy incentives and understanding the regulatory environment and its role in expediting offshore wind projectsAddressing constrained space challenges and construction processes and planning for serial productionCombining resources to update ports and shipyards that are not equipped to support floating offshore windIncentivizing young people to enter the offshore wind industry and training a specialized workforceEstablishing technology readiness and suitability for mass manufacturing and large-scale deploymentReducing risk by establishing clear deployment goalsSourcing raw materialsSourcing products that benefit local communities.Measuring how equative and sustainable the industry is in terms of impact on communities.Building a flexible and scalable supply chain
Floating Offshore Wind Subsea Balance of Plant Cost Savings Using a Risk Based Assessment Approach
Authors: Busby Meagan , Thethi Ricky , Fulton Tom
Published: April 2024

A risk based sampling approach for subsea inspections on the Balance of Plant (BoP) equipment in a commercial scale floating wind farm is presented. A lifecycle cost analysis is performed to compare a prescriptive inspection approach to a risk based sampling approach to demonstrate the cost savings benefit of the sampling approach.

The conceptual base case wind farm for the study has 60 × 15MW turbines on three-column semi-submersible floating foundations designed with a 30-year design life. The BoP equipment includes the floating foundations for the turbines and Offshore Sub Station (OSS), mooring lines, and inter array and export cables. The prescriptive inspection approach for the subsea BoP equipment is based on typical regulatory requirements such as those proposed by ABS, current fixed wind practices, and those used for Oil & Gas (O&G) assets. The risk-based sampling approach is based on selected key risks/failure scenarios that drive inspection activities and frequency.

A BoP subsea inspection lifecycle cost savings of over 30% can be achieved by using a risk based sampling approach instead of a prescriptive inspection approach. The risk assessment for the sampling approach is primarily driven by consequence cost considerations. Cost comparisons are made between un-detected threats that result in failure versus threats detected in time to mitigate or plan repairs in advance before failure occurs. The risk cost is the cost of the failure event times the probability of occurrence. Comparison is made to the cost delta for different inspection frequencies. Floating wind is a new industry with little reliability data available. However, O&G experience provides useful failure rate data that is used in this study. The risk based sampling approach considers degradation mechanism trends on inspected units that are extrapolated to other non-inspected units based on correlation between units. Monitoring can also affect the consequence of failure by providing early detection. Risk assessment should be conducted in the design phase as less conservative designs may save cost initially, but the higher risk may drive more frequent inspections.

The cost savings data presented in this study is of great benefit considering that O&M costs can amount to a substantial 30% of the total lifecycle cost. It is a novel study since it is specific to floating wind, which is a new advancement, and therefore does not have many papers available compared to fixed wind. It will also demonstrate key ways in which O&G knowledge can be transferred to floating wind.
Deepwater Emergency Pipeline Repair System Considerations and Challenges
Authors: Adamson I. , Chubb A.
Published: April 2024

Deepwater Emergency Pipeline Repair Systems (EPRS) are a suite of dedicated equipment manufactured, tested, and stored for the full life of the pipeline(s) in readiness to quickly perform a repair in the event of damage to the pipeline occurring. The requirement, design, manufacture, and storage of these systems carry Commercial and Technical challenges.

An overview of an EPRS will first be provided, followed by a review of the associated Commercial Challenges. Following this an outline of the Technical Challenges and Technical Drivers (decisions made by the design team which drive the direction of the system design) are discussed. Finally, three pipeline repair system case studies will be presented.

The requirement for an EPRS can range from it being a legislative requirement, a governmental license requirement, a commercial, reputational and environmental consideration, a requirement of the pipeline operators insurers, all focused on limiting loss of oil and gas transport volume should a breach of pipeline integrity occur. Considerations are often aided by detailed Front End Engineering Design (FEED) studies and can be supported by a pipeline operator consortium to share costs in a given geographical region.

The Technical Challenges are external factors, generally fixed parameters such as pipeline diameter, operating pressure or environment, and are not readily influenced by the EPRS designer. The EPRS Technical Drivers must accommodate all aspects of the pipelines performance envelope, but can be delivered by a range of different solutions optimised, technically and commercially, to fulfilling the specified scope. These drivers will be described further in this paper along with respective, technical, and commercial options.

This paper addresses three EPRS solutions that have been built: one deployed in West Africa, one currently stored in North West Australia in readiness for a repair and one built and tested for the Black Sea region.

This overview of the key challenges associated with a repair system, and how these have been solved on the three EPRS case studies, will provide valuable information to pipeline operators considering a Deepwater EPRS solution.
Development of an Electrically Actuated Inflow Control Valve for the Brazilian Pre-Salt Wells: A Reliability Approach, Challenges and Outcomes
Authors: Sawaguchi Ricardo N. A. M. , Noel Felipe. G. , Oliveira Felipe C. G. , Braga Arthur M. B. , Fernandes Marco A. S. , Santos Douglas S. , Kirnbauer Fernando
Published: April 2024

Brazilian Pre-Salt wells located in ultradeep water, capable of producing 70,000 barrels per day, have been, for years, strong candidates for Electric Intelligent Well Completions as means to increase the recovery factor of the fields in Santos Basin. For this purpose, an R&D project for an Electric Inflow Control Valve for 4-1/2 in. tubing string size, following a methodology for Technology Readiness Level progression and reliability adopted by the biggest Brazilian oil company, was carried out from 2014 to 2019.

Environmental conditions, like pressures up to 16,500 psi, temperatures up to 150 °C [302 °F] and differential pressure opening of 1,500 psi, were challenging to the tool design. Additionally, during the electric valve’s development, there was no technical specification for Electric Intelligent Well Completions, so standards like API 17F for the vibration of the embedded electronics boards were also followed.

The tool was divided into physical modules as part of a development strategy. That revealed to be a good approach, as some of those demanding specifications were not yet met in 2019 for testing the fully assembled prototype in any Brazilian laboratory. Test fixtures for selected modules, which would later be integrated into the prototype, were developed so that those parts could be tested individually. The full-scale prototype was then fully assembled and mechanically tested to attend the specified operational static axial loads and cyclic loading and unloading. A second full-scale prototype was built to perform flow characterization and erosion tests. At the end of the development, a System Integration Test, with a spool of tube encapsulated cable simulating their predicted length in a field installation, was performed to prove the actuation and sensing functionalities of the two prototypes with the subsea control boards and human-interface machine.

Results from the testing program and the performance the electromechanical actuation led to a second phase of the Electric Inflow Control Valve development focusing on improving the flow portion to achieve the resistance to 3,000 psi of differential pressure while opening. Moving from a printed-circuit board to a hybrid technology for the valve’s embedded electronics is also a necessary step to increase the reliability of the system and meet the operator’s target. By using the same concept-proven electromechanical actuator, with the addition of a fail-safe device, an Electric Surface-Controlled Subsurface Safety Valve is being developed. Both projects are expected to achieve the TRL 6 by the end of 2024.
Best Practices in Well Construction - The Journey to One Billion Barrels Oil Production in Bonga Field
Authors: Ojeh-Oziegbe O. , Okosun A. , Justus N. , Ezenwanne E. , Aribike O. , Adubi O.
Published: April 2024

In the fiercely competitive realm of brownfield oil and gas projects, our well construction team embarked on a transformative journey marked by unparalleled achievements, as outlined in this paper. This abstract sheds light on the strategic fusion of cutting-edge technologies, innovative processes, and the skill and expertise of the well construction team, which drove the remarkable recovery of over one billion barrels of oil in the illustrious Bonga Field. Navigating the intricate challenges inherent in brownfield environments, our team pursued a dual path of technological innovation and operational process optimization. The tangible outcome was a comprehensive suite of groundbreaking drilling and completion advancements that accelerated project timelines, brought wells online sooner, and substantially reduced well capital and operational expenditure. The achievements are multifaceted, encompassing the adoption of pioneering drilling technologies for extended horizontal reach wells and real-time wellbore visualization using lookahead tools, particularly in geo-steering within thin-bedded sands. Advanced wellbore placement, trajectory control, and drill string optimization significantly elevated flow rates and rates of penetration (ROP), accompanied by improved cuttings cleanup.

A strategic paradigm shift involved using offset well data for risk assessment and well planning, eliminating the need for redundant activities in every well based on available offset well data. Operations were streamlined by integrating various tasks into single runs, showcasing unprecedented efficiency gains. Crucially, our focus transcended hardware enhancements to embrace strategic procedural improvements, with proficient drilling supervisors wielding optimized Bottom Hole Assembly (BHA) configurations to push operational boundaries and enhance ROP, ensuring wellbore integrity. The culmination of these achievements propelled the Bonga project well beyond its production target, recovering over one billion barrels of oil. This abstract immerses the reader in the strategic orchestration of technologies, procedural enhancements, and the exceptional prowess of our team, offering profound insights into the dynamic interplay between human expertise and cutting-edge solutions in the realm of well construction. It is a testament to the extraordinary accomplishments defining our journey to surpassing one billion barrels in the Bonga Field.
Novel Techniques to Improve Sea-States During 1st End PLET Initiation
Authors: Ravirala N. , Alshafei F.
Published: April 2024

1st End PLET initiation is a common method considered for offshore pipeline installation. The 1st End PLET helps in supporting a direct permanent hold back system without any other operations by secondary, vessels. However, there are some associated factors that limit the use of 1st End PLETs. These limiting factors include the complicated design and fabrication of a hinged system, the relatively large anchor forging loads and seabed features that limit the length of chain/wire length for initiation. These factors have a direct impact on the limiting sea-states for offshore installation which may result in long weather downtime.

Subsea7 has considered novel ideas to improve the sea-state for a scenario where the wire length has been restricted for a 1st end initiation PLET with a permanent hold back system. Subsea7 has investigated the use of a stretcher wire that has the capability of straining up to 25% at very high loads without compromising the structural integrity of the initiation wire system. The stretcher wire was connected between two chain/wire segments for a hinged 1st end PLET installation. It has also been considered for a Stab and Hinge PLET initiation method. In both scenarios, there is an improvement in the limiting sea-state compared to the case using an initiation wire/chain without the ability to stretch.

This innovative method using a stretcher wire provides a damping effect in the initiation wire system which is highly beneficial. This damping effect reduces the peak stresses and strains that typically occur at the anchor forging section of a 1st end PLET/pipe interface during initiation. Furthermore, the stretcher wire does not have any limitation to use under any external hydrodynamic pressure. Hence, this selection could be beneficial for subsea operations at any water depth.

This paper will discuss and analyze the installation methods used and the screening for a suitable stretcher wire for given 1st end PLET initiation. The limitations and drawbacks that should be accounted before considering the use of stretcher wire for initiation will also be discussed.

Subsea7 has successfully installed a number of 1st end PLETs with such a stretcher wire. Some of these projects will be listed here. Finally, this paper will also introduce potential future developments that are being considered to further improve the PLET initiation sea-state by further dampening the 1st end PLET system.
Wandoo A – Reliability Methodology for Determination of Probability of Failure of a Braced Caisson Structure
Authors: Roberts R. , O’Brien C. , Sheppard R. , Moslehy Y. , Kitson M.
Published: April 2024

The Wandoo A (WNA) fixed platform was installed in 1993 with an intended service life of 15 years. It has subsequently undergone two 5-year life extension (recertification) studies – one in 2008 and another in 2013. The original design and both recertification studies followed API RP 2A WSD guidance (American Petroleum Institute, 2002).

The platform (see Fig. 1) is a braced caisson structure in 52m water depth. The structure supports five conductors: 1 through the main column, 2 external that penetrate through the skirt piles, 1 supported by an external riser caisson and 1 external. The foundation consists of five piles: 1 through the main column, 2 skirt piles, and 2 outrigger piles.

The system also features a tuned liquid damper (TLD) incorporated into the main column near El. (+)17m. This damper is intended to increase the structural damping and reduce system accelerations in response to environmental loading. The TLD is a set of three tanks filled to specific levels with water. The motion of the entrapped fluid provides the damping which has been tuned to the primary structural period.
Facilitating Digital Delivery: Advancements in 360° Visualization of Subsea Assets and Data to Aid Informed Decision Making
Authors: Hammond G. , Ferrari S.
Published: April 2024

A new digital solution to manage access, hosting, distribution, and analytics of subsea data. UTEC, a Geo-services brand in Acteon's Data and Robotics division, has launched "iSite Subsea", a game-changing, cloud-based platform giving users an intuitive interactive delivery portal for survey and inspection data, designed specifically to meet the needs of the offshore renewable energy market, and oil and gas subsea infrastructure owners.

For infrastructure owners looking to consolidate key geo-referenced survey and inspection information, iSite Subsea interfaces seamlessly with existing databases, resulting in long-term cost savings.

iSite Subsea helps to reduce costs, lower risk, enhance health and safety, and deliver better informed decisions. The new platform facilitates the digital delivery, throughout the lifecycle of an installation, of geophysical, geotechnical, structural integrity monitoring, inspection, and maintenance surveys, providing owners, developers, and contractors access to the data they need to plan, evaluate and solve safety, environmental and risk scenarios.

Challenges that iSite Subsea solves include: lack of access to data sources because they are held in different systemsthe struggle to ingest and make sense of the large volumes of complex datadecision-making based on experience and gut instinct rather than reliable metricsthe requirement for disparate, tailored databases and analysis tools.

These challenges are addressed through an interactive graphical visualisation, enhanced with "critical" data, as a powerful tool to drive informed decisions. The intuitive interface layers information and enables comparisons between data sets; a vital capability, particularly for repeat events such as inspections and maintenance.
Floating Substations Joint Industry Project
Authors: Berg K. N. , Mattson F. , Kochmann M.
Published: April 2024

DNV and 38 project partners have been working together in a Joint Industry Project (JIP) to identify, understand and tackle the challenges involved in taking the step from bottom-fixed to floating substations. A floating substation will be critical for many projects, to bring clean energy from floating offshore wind farms to the market and consumers. A floating substation is also a meeting point between different disciplines and stakeholders. The JIP involves a broad selection of the value chain representing this meeting point. The group includes both HV component and dynamic cable vendors, engineering companies, designers and yards and not the least companies that will operate and own; Developers and Transmission System Operators.

The objectives of the Floating Substations Joint Industry Project are to: (i) Identify technology gaps and the development and qualification efforts required close these gaps (ii) Identify gaps in standards and (iii) Establish joint understanding and alignment of best industry practice and technical requirements for design, construction, and operation of offshore floating substations. To meet these objectives, the project has defined a design basis, performed gap analyses, technology assessments and failure mode analyses for the key parts of floating substations. Both HVAC and HVDC systems have been addressed. Floater motion analyses and dynamic cable feasibility analyses have been performed and compared for suitability for carrying the HV equipment. Key questions to be answered include (i) what is the right safety level for design of a substation (or: what failure probability per year is acceptable) (ii) what are the motion characteristics of a substation and how does this compare to what the topside HV equipment can tolerate (iii) how can we qualify feasible export system designs. The project has undertaken defined activities to find answers to these questions.

The ultimate goal of the project has been to develop sufficient knowledge and cross-industry understanding to make floating substations a reality with an acceptable level of commercial, technical and HSE risk. The knowledge developed through the JIP will form basis for design standards for floating substations and dynamic cables. In this presentation, DNV will give an overview of the project results, the plans ahead for standard integration and required next steps.
A State-Of-Art Study on Solution to Liquid Hold-Up and Back-Pressure Management in Long Tieback Deepwater Gas Pipeline Network in Indian Offshore
Authors: Rathod P. R , Bansal R. , Hazarika S. , Ansari A. Z , Nischal R.
Published: April 2024

Deepwater long tie back subsea gas pipelines poses a critical operational challenge with declining pressure and production over the field life, the problem will further aggravate if early water breakthrough encountered. The pipeline networks exposed to such a low producing early water cut fields for long period of time will lead to accumulation of high liquid resulting in creation of additional backpressure which affect the well deliverability. The increase in water production in gas wells were started to cause unstable flow in one of the complex Deepwater (1300m) dual 14"x58 km subsea (with U loop) to shore network from Eastern offshore of India due to liquid loading, making flow assurance a challenge to daily operations.

An innovative liquid management strategy has been developed through extensive analysis and devised the methodology by Flow Assurance team in association with an integrated Operations team, in order to address the liquid loading issues by effectively utilizing the limited available resources and surface handling facilities. Continuous monitoring and dynamic simulation tools have helped to understand flow stability in the subsea network for minimizing liquid holdup which have significantly reduced the back pressure and resulted in enhanced production. An integrated dynamic multiphase flow model used to optimize operating philosophy after validation with field parameters and accounted for the uncertainty of the associated controlling parameters, and accordingly devised the sequence of steps for dynamic pigging to minimize liquid holdup. The sequential methodology comprises of reduction of operating pressure at process end for partial liquid knockout; optimized diversion of selective wells to maintain the hydrodynamic slugging within handling limit; flowing all wells via U loop to knock out rest of the liquid to the possible extent.

Successfully mitigated the issue by effective implementation of innovative strategy which proved to be highly efficient in maintaining production in a sustainable mannerly minimizing the liquid holdup and significant back pressure reduction.

This paper presents the details of the innovative methodology, devised and successfully implemented using state-of-the-art dynamic simulation tools. These steps were proved to be effective in field without need of any additional operational/capital cost in safe operating conditions. The framework presented here can be applied to any similar deepwater field with subsea long tie-back. This model is a handy tool not only for engineering simulation but for operator training and real-time surveillance as well.
Research on comprehensive analysis of patient comfort and complication rate using haemodialysis indwelling needles in AVF puncture in haemodialysis treatment
Authors: Jin Guihong , Gu Jianmin , Zhang Yan , Ren Shidan
Published: April 2024

Traditional needles for haemodialysis access can cause complications and discomfort. Indwelling needles may have advantages, but their efficacy needs to be investigated. Our study sought to compare the safety and efficacy of indwelling needles to traditional needles for haemodialysis access. A single-center retrospective study at the Pingyang County Hospital of Traditional Chinese Medicine included 70 haemodialysis patients. The intervention group used indwelling needles, whereas the control group used traditional needles. The rate of complications, limb mobility, blood chemistry, puncture success rates, operation times, haemostasis times, pain and comfort scores, and internal fistula failure rates were all compared. Overall, complication rates were slightly higher in the control group, but not statistically significant. Both groups improved their limb mobility and blood chemistry, but there were no significant differences. The intervention group had significantly higher puncture success rates (88.4% vs. 80.0%), shorter operation times (65.4 vs. 72.3 seconds), and faster haemostasis times (23.7 vs. 28.2 seconds) than the control group. Patients in the intervention group experienced less pain (3.7 vs. 4.2) and more comfort (8.1 vs. 7.5). The intervention group had slightly lower internal fistula failure rates (2.9% vs. 5.7%), but the difference was not statistically significant. Indwelling needles appear to improve puncture efficiency and patient comfort during hemodialysis.
Il senso del patire. Dolore e sofferenza nelle Lettres di Emmanuel Mounier
Authors: Zanchi Juri
Published: April 2024

Il patire rappresenta un’esperienza che ha perso di senso nella società contemporanea. Nel panorama culturale odierno, infatti, si registra una tendenza analgesica che vorrebbe preservare l’uomo dal dolore e dalla sofferenza, in quanto questi ultimi sono divenuti un male senza significato alcuno, che minacciano di rendere l’esistenza un’inutile e assurda miseria. Diverso è l’approccio di Emmanuel Mounier che nelle sue Lettres si è spesso confrontato, a partire dal piano esperienziale, con una venatura esistenziale del suo approccio filosofico, con il tema del patire, iscrivendolo dentro un originale orizzonte di significato aperto alla trascendenza e al cristianesimo. L’articolo si propone di approfondire la differenza fra il dolore fisico e la sofferenza biografica, e di cogliere, dentro la cornice delle relazioni umane, il proprium dei rapporti di cura, amicali, affettivi che trascendono le prassi mediche e, in qualche modo, le orientano idealmente. Nonostante la tendenza a medicalizzare il patire, l’esperienza della sofferenza continua irriducibilmente a riportare all’attenzione la domanda sul senso del vivere. Così stretto nella morsa fra la censura, l’accettazione e la rassegnazione, il patire, nel panorama mounieriano, ricopre il ruolo, oggi da riscoprire, di un’esperienza che può condurre ad una maturazione della persona, lungo le dimensioni della verità, dell’alterità e dell’amore.
Il dibattito in Bioetica - Defrocking white coat speakers: ethical and professional implications
Authors: Paola Frederick Adolf , Anderson Stephanie Lolita , Collier Kristin M. , Coulehan Jack
Published: April 2024

Not available.
CLINICAL CARE PATHWAY AND MANAGEMENT OF MAJOR BLEEDING ASSOCIATED WITH NON-VITAMIN K ANTAGONIST ORAL ANTICOAGULANTS: A MODIFIED DELPHI CONSENSUS FROM SAUDI ARABIA AND UAE
Authors: Al Raizah Abdulrahman , Alayoubi Fakhr , Abdelnaby Galal Hassan , Alzahrani Hazzaa , Bakheet Majid Farraj , Alskaini Mohammed A , Buhumaid Rasha , Awadhi Sameer Al , Kazim Sara Nooruddin , Jaiganesh Thiagarajan , Al Asiri Zohair
Published: April 2024

Background: The non-vitamin K antagonist oral anticoagulants (NOACs) have become the mainstay anticoagulation therapy for patients requiring oral anticoagulants (OACs) in the Gulf Council Cooperation (GCC) countries. The frequency of NOAC-associated major bleeding is expected to increase in the Emergency Department (ED). Nonetheless, we still lack local guidelines and recommendations for bleeding management in the region. The present Delphi-based consensus aims to establish a standardized and evidence-based clinical care pathway for managing NOAC-associated major bleeding in the Kingdom of Saudi Arabia (KSA) and the United Arab Emirates (UAE).
Methods: We adopted a three-step modified Delphi method to develop evidence-based recommendations through two voting rounds and an advisory meeting between the two rounds. A panel of 11 experts from the KSA and UAE participated in the consensus development.
Results: Twenty-eight statements reached the consensus level. These statements addressed key aspects of managing major bleeding events associated with NOACs, including the increased use of NOAC in clinical practice, clinical care pathways, and treatment options.
Conclusion: The present Delphi consensus provides evidence-based recommendations and protocols for the management of NOAC-associated bleeding in the region. Patients with major NOAC-induced bleeding should be referred to a well-equipped ED with standardized management protocols. A multidisciplinary approach is recommended for establishing the association between NOAC use and major bleeding. Treating physicians should have prompt access to specific reversal agents to optimize patient outcomes. Real-world evidence and national guidelines are needed to aid all stakeholders involved in NOAC-induced bleeding management.
Impact of daratumumab on stem cell mobilization and transplant in patient with newly diagnosed multiple myeloma: a real word single-center study
Authors: Passucci Mauro , Fazio Francesca , Micozzi Jacopo , Shafii Bafti Manhaz , Assanto Giovanni Manfredi , Piciocchi Alfonso , Martelli Maurizio , Petrucci Maria Teresa
Published: April 2024

Not applicable.
Combined effects of sugar-sweetened beverage consumption, screen-based sedentary behavior, and sleep duration on South Korean adolescent obesity: a cross-sectional study
Authors: Ra Jin Suk , Huyen Do Thi Thu
Published: April 2024

Purpose: This study examined the combined effects of sugar-sweetened beverage (SSB) consumption, screen-based sedentary behaviors, and sleep duration on adolescent obesity.Methods: It followed a cross-sectional study design and conducted secondary analysis on data from 20,497 high school students who participated in the 17th (2021) Korea Youth Risk Behavior Web-based Survey. This study underwent logistic regression analysis in complex sampling analysis.Results: The combinations of low and medium consumption of SSBs, excessive screen-based sedentary behaviors, and short sleep durations were associated with a 1.18 and 1.12 fold increased likelihood of obesity (95% confidence interval [CI]=1.03–1.35) and (95% CI=1.02–1.22), respectively. The combination of high SSB consumption, appropriate screen-based sedentary behaviors, and short sleep duration (adjusted odds ratio [aOR]=1.15, 95% CI=1.01–1.31) and high SSB consumption, excessive screen-based sedentary behaviors, and short sleep duration (aOR=1.40, 95% CI=1.16–1.69) were associated with obesity.Conclusion: Integrated and tailored programs considering combination patterns of SSB consumption, screen-based sedentary behaviors, and short sleep duration need to be developed for preventing adolescent obesity.
Association between smartphone overdependence and mental health in South Korean adolescents: a secondary data analysis
Authors: Yun Hyeseon , Choi Eun Kyoung
Published: April 2024

Purpose: The rising prevalence of smartphone overdependence among adolescents and its detrimental impact on mental health have become a growing concern. This study aimed to investigate the association between smartphone overdependence and the mental health of Korean adolescents.Methods: Participants were drawn from the 16th Korea Youth Risk Behavior Web-based Survey conducted in 2020. The dependent variable as smartphone overdependence, while the main exposure of interest was mental health, encompassing generalized anxiety disorder (GAD), perceived stress, sources of perceived stress, perceived loneliness, and perceived depressive symptoms. The study employed the Rao-Scott chi-square test and multiple logistic regression using IBM SPSS version 26.0.Results: The participants comprised 54,948 adolescents aged 13 to 18 years. Among them, 25.1% (n=13,775) were categorized as smartphone overdependence group. Specifically, 20.3% of adolescents who reported GAD ≥10 and 22.5% of those who reported experiencing high levels of perceived loneliness were identified as smartphone overdependent. The GAD increased a risk of smartphone overdependence by 2.61 times (95% confidence interval [95% CI]: 2.46–2.77). Perceived loneliness was associated with 1.98-fold (95% CI: 1.87–2.09) increased risk of smartphone overdependence. Additionally, conflict with peers was found to increase the risk of smartphone overdependence by 4.63-fold (95% CI: 3.89–5.52), followed by conflict with parents (odds ratio [OR]: 4.52, 95% CI: 3.84–5.31), and family environment (OR: 4.52, 95% CI: 3.75–5.46).Conclusion: The findings underscore a significant association between smartphone overdependence and mental health in Korean adolescents. Healthcare services to improve their emotional coping and interpersonal skills are necessary.