bluuebunny/crossref_metadata_2025_split huggingface dataset:
De-Risking Downhole Disconnection Tools for Open Hole Intelligent Completion in Deepwater Wells
Authors: Schnitzler E. , da Silva Jr. M. F. , Oliveira Jr. A. F. M. , de Oliveira F. S. , Roman R. S. 
Published: April 2024

Abstract
This paper presents how Petrobras, in collaboration with suppliers and other operators, proceeded with a qualification and deployment plan for one of the new technologies recently introduced in its pre-salt wells. It covers the new downhole disconnection tools for control lines used in intelligent completion systems deployed in open hole, also known as WDT – Wet Disconnect Tool. Downhole disconnection systems allow connecting and disconnecting the tubing and control lines, hydraulic and electric, between the upper and lower completion. This equipment is frequently used when the ICVs are deployed in open hole, as applied in the latest pre-salt projects in Brazil.
However, a successful performance of these tools may be severely impacted by downhole conditions and the intrinsic challenges in deepwater wells. High mechanical loads, pressure and temperature variations, aggressive wellbore fluids and the presence of debris are just some of the concerns. Therefore, the operator has set a robust qualification plan to de-risk the introduction of this technology in its offshore fields.
In strong collaboration with the suppliers, the possible weak points and risks were identified and addressed in the qualification plan. This development was also guided by reliability targets for the final systems, based on reliability tests at component, sub-system and system levels.
One of the main concerns was to establish a successful connection in the well between the two parts of the tool. Despite all the efforts to clean the wells before completion deployment, the presence of debris is always a risk, and some debris tolerance need to be considered. A representative mixture of debris was defined for the connection and disconnection tests, mimicking wells conditions as much as possible.
The overall development and qualification of the tools was successfully finished, after several changes in the original designs. In the end, the tools showed good debris tolerance and positive expectations in terms of the performance in downhole conditions. The trial wells, where the tools were deployed already connected (single trip), faced no issues related to the new tool. Dual trip installations are expected to happen shortly.
The innovative use of downhole disconnect tools in deepwater wells opens several opportunities for projects that benefit from the use of intelligent completion. Improving these tools robustness and reliability helps building the necessary confidence for this kind of application. Future opportunities of incorporating downhole fiber optics sensing in the lower completion and electrically actuated valves also benefit from this experience.
Subsea Hydrogen Long Duration Energy Storage
Authors: Labes A. , Myhre T. 
Published: April 2024

Abstract
Nations around the world are progressing in adding renewable sources of energy to their grid as an attempt to meet CO2 emissions targets and provide power to increasing demand. The higher portion of intermittent renewables like solar and wind to the electrical grids have created a need for technologies that can not only provide resilience to the grids, but also have low greenhouse gas footprint. Long Duration Energy Storage (LDES) technologies are currently under development to fill this gap. Of the many LDES technologies, Hydrogen based systems is proposed as viable energy storage system for very long periods, including interseason periods, where hydrogen is stored in salt caverns.
In this paper we describe an alternative LDES system based on hydrogen, where hydrogen is stored in pressure vessel at the seabed. Subsea storage provides a safe location for a large mass of hydrogen to be stored at a stable temperature environment, while requiring a reduced footprint on land, and providing geographic flexibility.
The subsea hydrogen LDES system can fit a space where power can be provided for 10-100 hours, or more depending on the application, and by so, performing an economical mean to integrate renewables to a grid, or to enable a full renewable based grid to be sustained in isolated islands.
Macro-Models for Anchor and Chain-Soil Interaction in Floating Offshore Wind Analyses
Authors: Jostad H. P. , Rui S. , Zhou Z. , Wang Y. , Huynh D. V. K. 
Published: April 2024

Abstract
A numerical formulation is introduced for modelling the dynamic interaction between the mooring line (chain) and the soil, extending to the connection point at the anchor (pad-eye) in a fully integrated analysis of an offshore wind turbine generator, floating support structure and mooring system including the anchors. The anchors and the segments of the mooring line in contact with the soil are modelled by macro-models. The macro-models describe the coupled non-linear relationship between incremental displacements and the resultant soil reaction forces at each node along the mooring line in contact with the soil and at the pad-eye in a 3-dimensional space. The calibration of the input for two distinct types of anchors - suction caisson anchors and fluke anchors in clays, is presented. By implementing these macro-models into a tool for simulating the dynamic behavior of the floating offshore wind turbine, the design process of the anchors can be faster and more accurate. Importantly, a holistic approach to the mooring system design, including the interaction with the soil, has the potential to optimize the design and reduce the costs. It also enables the prediction of the potential development of complex mechanisms such as seabed trenches during repeated motion of the mooring line in contact with the soil. An example is briefly presented to demonstrate the application of this integrated analysis of floating offshore wind turbines, emphasizing the additional input required.
Risk-Based Inspections Using Digital Twins for Hulls and Structures of Floating Assets
Authors: Stensrud E. , Bjørdalsbakke H. O. , Hamre G. , Raeissi B. , Richardsen T. , Torstensen Are , McKay D. 
Published: April 2024

AbstractThis paper presents a research and development project undertaken by DNV to develop digital twins of hull compartments on floating assets, wherein inspection findings are collected and documented for analysis and reuse. This process aims to drive increased efficiency in future inspections. Data gathering is performed by intelligent autonomous drones capable of self-navigation in structurally complex compartments. These are coupled with AI-driven algorithms that detect and identify findings such as cracks, corrosion, and deformations. The project serves a dual purpose: firstly, to reduce the need for manned entry into hull compartments, and secondly, to enhance the efficiency of planning and execution of future inspections. This is achieved by ensuring known findings are identified, mapped in the digital twin, and can be easily located and reassessed.The drones are equipped to perform both close and general visual inspections, although further development in lighting is necessary to support general visual inspections of surfaces in large hull compartments. The surveyor then reviews the inspection findings and identifies actual defects, which contributes to the continuous learning of the detection algorithm. Successful trials have been conducted with both free-flying and tethered drones.Future development is planned to focus on improving automated inspection planning and visualization for monitoring compartment conditions. Additionally, enhancements are aimed at increasing the capability for anomaly detection, improving drone navigation in structurally complex spaces, and enhancing the capacity for data gathering while in motion.
Practical Qualitative and Quantitative Models in Carbon Capture Utilization and Storage Risk Assessment
Authors: Sneddon J. , Busby A. , Hurst S. 
Published: April 2024

Abstract
Carbon Capture Utilization and Storage (CCUS) has been recognized as a tool to aid the decarbonisation of carbon heavy industries, with the storage of CO2 in the subsurface over geological timescales being a key component in the CCUS process chain. Assessing and managing the risks involved in subsurface storage of CO2 is required so decisions can be made about the design, operation, monitoring and acceptability of potential projects. As with existing industrial activities, a number of approaches exist for assessing risk ranging from purely qualitative approaches through to quantitative approaches.
A structured, proportional risk assessment approach is proposed, aimed at identifying, analysing and evaluating the risk from a candidate subsurface store through a combination of qualitative and quantitative techniques to gain the most benefit. Development of a register of subsurface containment risks allows for the identification of scenarios of concern, which can be coupled with risk matrices to provide an estimation of the risk level together with its acceptability. More in depth qualitative techniques such as bowtie analysis encourage different disciplines to collaborate and enhance communication, both internally and externally, of the controls present for the most significant risks. The combination of bowties with a quantified, event tree-based model can allow for numerical determination of leakage probability and magnitude. Quantitative methods can therefore estimate insurance liabilities and allow comparison of options or with acceptance criteria. However, these assessments are underpinned by the quality of inputs. Given that the CCUS industry is still in its infancy, data surrounding event likelihoods and leak magnitudes, especially for geological leakage pathways, can have large amounts of associated uncertainty; this uncertainty must be taken into account when evaluated the overall acceptability of projects. Whilst both quantitative and qualitative methodologies for risk assessing subsurface CO2 storage have their advantages and disadvantages, it is when combined as part of a structured CCUS risk assessment approach that the most benefit is gained.
Enabling the Electrification of Offshore Activities – Co-Demonstration of Next-Generation Autonomous Offshore Power System and Resident, Uncrewed Mobile and Static Assets at PacWave Wave Energy Test Site
Authors: Hammagren E. , Lesemann A. R. 
Published: April 2024

Oceans cover two-thirds of the earth's surface and form the world's biggest and best – yet largely untapped – battery. Ocean waves have more energy density than other renewables, including wind, solar, and biomass, and have the potential to supply 4x the world's annual energy consumption (Masterson, 2022; Zic, 2020). In addition to the impact wave energy can have on decarbonizing and diversifying the electric grid, it offers a significant value proposition in the emerging blue economy sector (LiVecchi et al, 2019). The blue economy consists of industries operating offshore, including shipping, oil and gas, defense and security, aquaculture, and research. These industries require bringing people and energy on site to perform daily work, but current energy costs in the blue economy are extremely high. The prevailing processes are complex, including shore dependencies and fuel transportation logistics. Few alternatives for reliable power generation exist, with the most prominent being high cost and high carbon emissions diesel generation. Because of this lack of affordable, reliable power, the trends of electrification, digitization, and automation that have led to substantial innovation and improvements in the terrestrial economy over the last two decades are slow to come to the blue economy.
An Autonomous Offshore Power System (AOPS) provides a cost-effective power solution for the blue economy. An integrated system consisting of power generation, energy storage, asset management, and data communications, an AOPS can transform how industries operate in the ocean today. They can enable autonomous, digital, longer-residency assets and drive lower cost, complexity, and carbon-intensity.
The U.S. Department of Energy-sponsored PacWave South test site, slated to open off the Oregon coast in 2024, provides a critical test facility for AOPS technologies. The focus of this paper is the process of designing and building a third-generation AOPS for testing at PacWave South, incorporating lessons learned from three previous design, build, and test cycles.
Marlim & Voador – XT Life Extension and Reuse
Authors: Soares R. F. , Fonseca M. M. Capella da , Palmieri I. , Diehl B. , Orlowski R. T. , Aguirre M. H. , Filho P. T. Diniz , Pereira R. M. , Gomes A. L. , Barros L. O. de , Bueno M. N. 
Published: April 2024

Abstract
The Marlim and Voador fields revitalization project aims to extend their production until 2048 through the deployment of two new FPSO units, combining the drilling of new wells with the utilization of aged wells. The project also includes the replacement of existing units, improving field efficiency, and reducing CO2 emissions.
This paper describes the methodology used for the XT life extension and reuse in the Marlim and Voador fields.
In the producing wells it was only possible to reuse the full clad XT, because the corrosion rates worsen significantly for future conditions, where wells with high CO2 contents will be interconnected to the FPSOs, contaminating the gas-lift of all wells. On the other hand, the XT of the water injector wells could be mostly reused, although the corrosivity of the water injected in the future is potentially more severe, due to the reinjection of produced water.
The analysis of technical reports showed that most of the XTs were approved for reuse, with valve integrity being the main reason for rejection. The reuse of XTs significantly contributed to the project’s Net Present Value (NPV) and resulted in the avoidance or postponement of approximately 48 ktons of CO2 emissions.
Well Construction Records and its contribution for Campos Basin Revitalization
Authors: Duccini L. E. A. , Petersen F. C. , Júnior A. C. R. , Marques M. , Miranda J. P. 
Published: April 2024

Abstract
In the Campos Basin, Petrobras discovered the first giant fields in the 1980's, which led to a technological development enabling worldwide deepwater production and later, the production of the Pre-salt fields. Additionally, the achievements in Marlim and Roncador fields have earned two OTC awards. Over the past 40 years, more than 14 billion barrels of hydrocarbons have been produced in the Basin, and it currently accounts for approximately 25% of Brazil's total production.
Despite its historical significance, the Campos Basin faces challenges related to declining production from mature fields, as many productions units and wells are reaching the end of their lifespan, requiring investments in infrastructure and exploration. However, the basin still holds significant untapped resources, providing opportunities for future development and growth, as the main Concession contracts have been extended beyond 2048.
New projects have been conceived and integrated into Campus Basin Revitalization Program (Marlim, Albacora and Barracuda), in which Petrobras plans to invest U$22 billion up to 2028. However, ensuring the viability of brownfields projects requires careful control over Capital Expenditures (CAPEX) and Operational Expenditures (OPEX), or the costs of well construction would impact deeply in the project benefits.
This paper provides an overview of the efforts made by well engineering regarding design, practices, and processes implemented in recent years to enhance performance in well construction, enable economically marginal projects, and add greater value to the projects in the Campos Basin.
Latest Industry Data and Flexible Pipe Integrity Management Lessons from the Sureflex JIP
Authors: MacLeod I. , Picksley J. , Birmingham M. , Moir A. 
Published: April 2024

Abstract
The 5th phase of the Sureflex Joint Industry Project (JIP) provides the latest data-driven industry guidance relating to unbonded flexible pipe population and damage / failure statistics, integrity management guidance and good practice. To maximise knowledge and experience sharing, the full deliverable report has been made freely available through an open industry publication. This paper shares the key findings of the JIP.
The JIP gathered data from the industry, with wide global member support from flexible pipe suppliers, operators, and regulators, and a wide range of non-member stakeholder organisations. The data is gathered, assessed, desensitised and presented to provide the best possible integrity management guidance to pipe users. The JIP also included a series of workshops: assessing vendor inspection, monitoring, and repair technologies; evaluating other key flexible pipe challenges, and sharing of operational experiences, with the key findings presented in the main JIP report. An ongoing network continues and expands the sharing of data and lessons learned.
Whilst flexible pipe technology may be considered as mature, being commercialised in the 1970s, there has been an almost 1/5th increase in the volume of pipes delivered in the latest five-year period. This indicates an increasing volume of use, and the JIP data demonstrates the pace of technology acceleration of design parameters, as users of the technology seek to stretch the operational envelope.
The manufacturers continue to perform product research, development and qualification to meet this demand, though this has not prevented the emergence of a limited number of new failure modes. Reported Leak and Damage rates have shown a decreasing trend over the last 20 years, however the incident rate for rarer Rupture events has increased for Riser applications since 2011. These rupture events have been attributed to a relatively small number of failure mechanisms in specific applications, some of which have emerged in the last 5 years.
Important developments of existing and new inspection and monitoring technologies have continued, though further work to improve the reliability, ease of deployment and usability is required. Knowledge and experience sharing of successes and failures is key to ensuring that appropriate and relevant guidance is maintained and made available to the wider industry.
Building on the knowledge shared through the preceding JIP phases dating back 25 years, this initiative has compiled and shared the most comprehensive industry dataset of unbonded flexible pipe supply experience, damage and failure data, and corresponding integrity management mitigations in the form of guidance and good practice.
Accelerating Offshore Windfarm Site Characterization Using Deep Learning
Authors: Di H. , Simoes V. , Zhao T. , Abubakar A. 
Published: April 2024

Abstract
Developing offshore wind farms requires effective mapping of shallow subsurface for turbine foundation design, construction, and monitoring, all of which face many challenges in especially field data conditioning, structure interpretation and modeling, and geotechnical property estimation. In this paper, we revisit these challenges from the perspective of pattern recognition and propose implementing deep learning (DL) into automating three essential tasks in windfarm site characterization, including (i) cone-penetration testing (CPT) data conditioning, (ii) ultra-high resolution (UHR) seismic horizon picking, and (iii) integrated geotechnical property estimation, which leads to an accelerated workflow for delivering reliable ground models in an offshore windfarm site of interest. Specifically, the CPT data conditioning aims at identifying outliers in CPT data and reconstructing missing segments via a 1D auto-encoder. The UHR seismic horizon picking aims at tracking key horizons in collected UHR seismic via a two-step supervised DL and building a horizon model that captures the primary structural patterns in the target area. The integrated geotechnical property estimation aims at integrating the reconstructed CPT logs, the UHR seismic images, and the horizon models into simultaneously estimating multiple geotechnical properties such as cone-tip resistance (RES) and friction ratio (FRR) via semi-supervised DL. As tested over the public Borssele dataset within the Dutch Offshore Windfarm Zone, the proposed DL-accelerated workflow successfully improves the quality of CPT data, picks multiple major horizons that reflect the complexities of shallow subsurface, and constructs the corresponding RES and FRR models that delineate the lateral variations in geotechnical across the Borssele area.
Life Cycle Costing Application in the Energy Sector – Technology Applications
Authors: Mattioli M. , Willmann E. , Østebø R. , Paulsen E. H. 
Published: April 2024

Abstract
This paper presents use cases of the ISO 15663:2021 standard for industry cost management and business value crea-tion. The standard contains requirements and guidance on how to implement and apply the life cycle costing methodology, to provide decision support for selection between alternative competing options. The objective of the paper is to show recent indus-try applications and how value can be created by application of life cycle costing in oil & gas, particularly focusing on new technology development and lower carbon energy solutions.
ISO 15663:2021 provides a framework for value optimization over the entire life of an asset. It promulgates a manage-ment methodology and application of life cycle costing across all life cycle phases. The purpose is to provide decision support for selecting between alternative options for relevant life cycle costing subject matters.
The life cycle costing applicability to new technology innovation that can replace conventional technology will specifically be addressed based on recent operator and supplier studies.
The use case concerning the deployment of subsea drones in subsea field development is presented. Subsea drone deployment is one of most challenging improvement for the oil and gas industries, being a game changer for the carbon footprint and cost reduction of operations. The ISO 15663:2021 has been applied in order to guide the decision maker throughout a proper selection of different competing options and enabling a fully representative life cycle cost analysis.
The paper also presents an example of use of life cycle costing to compare and evaluate differences in business performance, as well as opportunities, between conventional topsides and Subsea Chemical Storage and Injection System (SCSIS) for subsea wells. The methodology served as a comprehensive tool for comparing the life cycle cost of two alternative options.
Oil & Gas Operators as well as Contractors and Vendors are the main users of ISO 15663:2021. Besides the use cases presented in this paper, the ultimate goal of the authors is to demonstrate that by using a proper life cycle costing methodology, the decision making can be ultimately rigorous and coherent.
FIRSTLING-DIGIMAR, a Pilot Scale Digital Twin of a Marine Riser for Field Use
Authors: Kharami E. , Mentzelopoulos A. , Prele E. , Shukla K. , Wang Z. , Bray B. , Cao Q. , Singh A. , Fan D. , Sapsis T. , Triantafyllou M. S. , Karniadakis G. E. 
Published: April 2024

Abstract
We developed and tested in real time FIRSTLING-DIGIMAR, a pilot scale digital twin of a marine riser driven by sparse field measurements. The FIRSTLING consists of hardware and software that includes a reduced order model developed through multi-fidelity methods combining massive field and experimental data, with low- and high-fidelity models, it is driven by real time measurements of a few sensors along the riser, and provides real-time fatigue life predictions with uncertainty quantification.