bluuebunny/crossref_metadata_2025_split huggingface dataset:
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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

Abstract
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.