bluuebunny/crossref_metadata_2025_split huggingface dataset:
Pseudo 3D UMASW For Offshore Windfarm Development
Authors: Unterseh S. , McArthur L. , Mouton E. 
Published: April 2024

Abstract
In the frame of a Research and Development (R&D) project dedicated to quantitative ground modelling, Underwater Multichannel Analysis Surface Waves (UMASW) data were acquired within an offshore windfarm area currently in development in North Sea. The ultimate goal of the project described in this paper was to test the added value of the shear wave velocity (Vs) interpreted from the UMASW, particularly as a propagation tool of the geotechnical information. This requires a suitable Vs dataset within the foundation depth and the quantification of the associated uncertainties. The Vs of the ground is generally accessed in one dimension (1D) through geotechnical borehole (P-S-Primary & Shear seismic wave- logging or laboratory sample testing) or through S-CPT (Seismic Cone Penetration Test) in-situ testing within the offshore wind industry. The present acquisition was then an opportunity to compare both UMASW and borehole results, and to assess the spatial variability of the Vs around the boreholes.
The UMASW acquisition was designed to allow a pseudo three-dimensional (3D) gridding of the data, with a 10m bin size, and to reach a minimal signal penetration depth of 60m below seabed (bsb), compatible with the geotechnical investigation. Two block areas of about 400m × 300m, each centered around a borehole location, have been investigated together with a corridor area of 2300m × 20m tying the blocks. The spread used for the acquisition includes a sledge equipped with a 60cu.in airgun and a 166m long streamer with 48 channels. The sledge, dragged on the seabed, was tracked along intended 10m spaced lines with a shot point interval of 10m. The data processing was done for each shot and includes the manual picking of the dispersive curves and a 1D inversion modelling. The pseudo 3D gridding was then carried out by interpolation with the closest neighbors.
The results are found to be of good quality, with clear dispersive curves and a signal penetration reaching about 80m bsb. The standard deviation of the processed Vs remains generally below 3%. A first comparison of the Vs with the existing 2D Ultra High Resolution Seismic (UHRS) reflection data shows a good stratigraphic match with the key seismic horizons, while detailing some significant variability across the corresponding units. While UMASW, together with seismic refraction, is regularly used to characterize the ground for burial or trenching purpose, it appears to also bring valuable design parameters for the offshore wind turbine foundations.
Setting the Stage for a Novel Mooring Chain Integrity and Design Assessment Practice: The Partial SCF and Hot-Spot S-N Curve Approach
Authors: Nair A. , Dhaigude M. , Yao A. , Chen Y. , Jaiswal V. , Shavandi M. 
Published: April 2024

Abstract
Mooring chain's integrity is vital for offshore floating production units since their function ensures the required station keeping ability of the unit and protects the unit and associated critical assets such as risers. The decision of when to keep or replace a corroded chain is important for operators in the offshore oil and gas industry. While this topic has been a subject of several studies, actual fatigue consumption of a mooring chain due to corrosion, in-service loads and predicting the remaining fatigue life of the same chain in permanent floating structures remains a challenge. Incidents of premature mooring line failure has raised concerns on validity of mooring chain reliability in Industry Standards. This paper investigates the probability of failure of mooring chains based on available failure statistics, and its implication on current design and life extension practice. A partial SCF approach is proposed to assess fatigue life of corroded mooring chains. The approach was developed and validated through Fatigue of Corroded Chains (FoCCs) Joint Industry Project (JIP). In addition to the FoCC JIP validation, this paper presents application of the proposed approach on two recent corroded chain fatigue tests to predict its cycles to failure without FEA assessments.
High Temperature Compatible, Field-Deployable Heat Exchanger Nanocomposite Treatments
Authors: Uttley Katherine , Galvan Anika , Nakatsuka Matthew , Basile Marco 
Published: April 2024

Abstract
Fouling of refinery reboilers is a major source of production loss, health, safety, and environment (HSE) issues, and increased carbon emissions. Reboilers can be especially difficult, as fouling is difficult to address without major cleaning operations, and anti-fouling solutions outside of design modifications are limited.
Formulation development of a novel coating material for reboiler systems examined a wide variety of polymer and nanocomposite chemistries. An iterative development process was used to identify and synthesize a polymer nanocomposite surface treatment to protect against corrosion induced by the buildup of chloride and sulfide salts typically found within distillation reboilers. Application on carbon steel test panels was completed using industry standard spray application methods and subsequently characterized for adhesion strength, thermal stability, chemical compatibility, and corrosion mitigation.
Data included in this study will demonstrate that the material has a durability comparable to existing state-of-the-art coating materials (following ASTM D3359), chemical resistance to high acid and base solutions, and corrosion resistance (following ASTM B117) to support the long-term use of this novel surface treatment to protect metallic surfaces in harsh process conditions. Use of this novel material, compatible up to 350°C, has suggested the overall lifetime of the candidate reboiler system could be increased 2-fold based on previous applications of similar materials in field deployment.
This non-fluorinated, highly chemically resistant surface treatment can offer significant cost avoidance through the improvement of operational uptime and reduced maintenance costs in heat transfer applications typically susceptible to corrosion and fouling.
Intelligent Optimization of Ultra-Deepwater Oil Transmission Risers Using an Enhanced Graph Neural Network
Authors: Zhu Hong , Yang Jin , Xue Rui , Dai Shenghui , Zhan Shibo , Li Gengchen 
Published: April 2024

Abstract
With the continuous global demand for oil and advances in deepwater drilling technology, the development of deepwater oil and gas resources has become increasingly important. Steel catenary risers play a crucial role in connecting subsea and surface facilities. However, complex marine conditions in ultra-deepwater environments pose significant challenges to the design of SCRs. To achieve efficient and reliable operation of SCRs under these extreme conditions, this study proposes an intelligent optimization design method based on enhanced Graph Neural Networks. Initially, considering the structural characteristics of the SCR dataset, graph data features comprising various nodes were constructed. Subsequently, an enhanced GNN model was obtained through cross-validation and Bayesian hyperparameter optimization, incorporating Graph Attention Networks with pooling layers, which achieved exceptional results in predicting dynamic responses of SCRs. Utilizing this model, multi-objective intelligent optimization of SCRs in the South China Sea region was conducted, and the optimization effects were validated through simulation. The results show a reduction of 26.76% in maximum top tension and 24.15% in Max Von Mises at the touchdown point, with wave-induced fatigue life and vortex-induced motion fatigue life improved by 24.31% and 63.16%, respectively.
This research demonstrates that enhanced GNNs can efficiently learn the data relationships between different node features of SCRs and realize their effective optimization under extreme marine conditions, offering a reliable optimization design solution for ultra-deepwater oil and gas resource development. This approach opens new avenues for the optimization design of other marine structures.
Reducing Time-Lapse Seismic Data Acquisition Cost with Deep Learning
Authors: Hu W. , Phan S. , Li C. , Abubakar A. 
Published: April 2024

Abstract
Time-lapse (4D) seismic is one of the most important tools for monitoring of subsurface reservoir production. However, repeated monitoring data is time-consuming and expensive. To reduce monitoring data acquisition cost and the subsequent 4D data processing, we developed three novel deep learning powered algorithms to solve challenging problems including sparse monitoring seismic data reconstruction, simultaneous source shooting monitoring data deblending, and rapid subsurface property estimation directly from very sparse pre-migration seismic data. These algorithms exploit the subsurface information buried in the baseline data and then transfer the learned knowledge to the monitoring data, which narrows down the sampling space of deep learning network to circumvent the network generalization challenge for optimal network inferencing. Customized network architectures and special learning strategies were designed to overcome specific challenges in each individual application. For sparse data reconstruction, we adopted a self-supervised learning approach combined with two-pass learning workflow to improve computation efficiency. A two-stage network was developed to enhance the deblending accuracy while preventing the non-uniqueness issue. A unique deep learning method was proposed to estimate the subsurface property change due to production or other activities such as CO2 sequestration directly from a few pre-migration seismic gathers without being contaminated by strong artifacts that are often observed using conventional imaging or inversion algorithms to deal with sparse gathers. The numerical experiments demonstrated the accuracy and efficiency of these deep learning algorithms on both synthetic data and field data.
Process-Oriented Validation of HYCOM-TSIS Reanalysis Runs for the Northern Gulf of Mexico
Authors: Ivanov L. , Arena R. , Bozec A. , Chassignet E. , Longridge S. , Ramos R. , Srinivasan A. , Iskandarani M. 
Published: April 2024

Abstract
The Tendral Statistical Interpolation (T-SIS) package is used with HYCOM to produce the reanalysis hindcast. To assess 1/25° and 1/100° resolution model hindcasts’ performance, model results were compared to independent ADCP current measurements from several sites in the Northern GOM impacted by passing Loop Current Eddies, Deep Cyclonic Eddies (without a clear surface expression) and Tropical Storms. The comparative analysis of HYCOM-TSIS reanalysis data and ADCP measurements showed a good qualitative and satisfactory quantitative agreement between model and observations. Of most importance, the model with the T-SIS package resolves the general kinematic structure of subsurface flows associated with the Deep Cyclonic Eddies, reflecting a substantial improvement of the model skill compared to the previous version of the hindcast.
A comparison Study of the Mooring Simulation in the Design and Analysis of Floating Offshore Wind
Authors: Zhang F. , Wood C. , Wang Q. Q. , Nekstad O. J. 
Published: April 2024

Abstract
In wind turbine design, various critical aspects demand attention, including wind turbine design, assessment of floater structure, and optimization of the mooring system. Turbine designers prioritize control system optimization, relying on predicting responses like power generation and nacelle accelerations. Evaluating floater structure involves motion responses and loads on interface positions, like the tower base and mooring fairleads. The latter is crucial for positioning system optimization. These considerations often necessitate a comprehensive simulation of the entire system.
This paper conducts a comparative study of outputs of wind turbine, motion performances of the floater, and tensions of the mooring lines, involving various simulations using different mooring models, exploring both frequency and time domains. In the frequency domain, it begins with hydrodynamic analysis using equivalent springs and proceeds to a statistical analysis with a catenary mooring line model. Emphasizing time domain analysis, the paper extensively compares results from coupled analysis with a quasi-static catenary mooring model and a dynamic finite element mooring model. The wind turbine and floater models are kept identical, encompassing three power generation design load cases and two parked cases. The assumption is that the quasi-static approach can significantly reduce coupled analysis time, prompting an examination of its accuracy for the mentioned design focuses.
The conclusion reveals that, overall, the results for wind turbines and the tower—such as power generation, nacelle accelerations, and tower base moments—are very similar using two different mooring models in time domain analysis. Regarding floater motions, both approaches yield comparable results in the wave frequency range, but the quasi-static model tends to overpredict low-frequency responses. This conservative tendency affects global performance prediction more than structure assessment, as the latter mainly relies on wave frequency responses. Fairlead tension statistics show similar outcomes, but the power spectrum density indicates that the quasi-static mooring line may miss dynamic aspects. For capacity checks, the quasi-static approach remains valid, while it's recommended to use the dynamic FEM mooring line model for fatigue checks. A simplified approach may still be practical to streamline analysis for design iterations.
Geologic Considerations for Floating Offshore Wind, Gulf of Maine, USA
Authors: Rasmussen T. , Peralta P. , Fisher J. 
Published: April 2024

Abstract
The Bureau of Ocean Energy Management (BOEM) has designated call areas within the Gulf of Maine outer continental shelf in water depths suitable for floating turbines (i.e., greater than 100 m). The objective of this study is to present an overview of the geologic and geophysical conditions and constraints within the Gulf of Maine where potential lease areas may be located. This work expands on the previous 2022 BOEM-funded desktop study supporting the US Department of the Interior, Bureau of Safety and Environmental Enforcement’s solicitation for areas of interest to the Bureau of Ocean Energy Management Technology Assessment Program on offshore wind technology (BAA No: 140M0121R0006) (Fugro 2022).
The study utilized public domain geophysical and geotechnical data to evaluate the seafloor and near-seafloor geological and geotechnical conditions relevant to floating offshore wind. Data available from published scientific literature and offshore projects were integrated and evaluated using GIS and seismic interpretation software to identify and map geohazards, seabed and subsurface conditions, and key stratigraphic geotechnical units. These results are presented as maps illustrating seabed and subsurface conditions, including geohazards.
Our evaluation of the study area indicates generally favorable conditions for offshore wind development, with site-specific considerations to be factored into engineering design. Key findings related to geological conditions include exposed bedrock, glacial deposits (including exposed glacial till and boulders), and very soft fine-grained sediments. Based on these conditions, the suitability of various foundation concepts is discussed. Other conditions include ocean usage, from fishing activities to vessel traffic. This paper will highlight potential geohazards and provide developers with an understanding of geological and geotechnical conditions in the call area. Understanding of geologic and geotechnical conditions will aid in feasibility assessment for floating wind developments within the Gulf of Maine call area.
Time and Cost-Efficient Characterization of Inlet Hydrodynamics for the Development of Tidal Energy Projects
Authors: Challa R. , Ravens T. M. , Duquette D. 
Published: April 2024

Abstract
In furtherance of advancing a tidal energy initiative, Littoral Power Systems, Inc. (LPS) endeavors to conceive, construct, and assess a comprehensive marine and riverine hydrokinetic current energy conversion apparatus within the Kootznahoo Inlet (Angoon, Alask a) under the aegis of the Advanced Research Projects Agency-Energy (ARPA-E) – Submarine Hydrokinetic and Riverine Kilo-megawatt Systems (SHARKS) project. Systematic surveys of tidal flow velocities, bathymetry, and water levels within the inlet were conducted to discern spatial and temporal flow variations, pinpointing the optimal deployment location for the device. Quasi-synoptic measurements of current speed and direction were captured along cross-inlet transects at the projected location of maximum flow velocity employing an Acoustic Doppler Velocimeter (ADCP). In tandem with these measurements, sophisticated one-dimensional (1D) DYNLET and Delft3D hydrodynamic circulation models were developed for the inlet. The numerical models were pivotal in extrapolating from flow measurements, thereby providing a thorough characterization and validation of spatial and temporal variations. Calibration and validation of the models were achieved using measured transect velocity data, subsequently employed to predict velocity estimates across the inlet throughout the tidal cycle. Comparative analyses revealed the consistent identification of the most robust flows during peak flood and ebb tide, proximate to the southeast side of the inlet (adjacent to the Village Rock) in relatively shallow water depths. The determination of tidal energy resources often entails a time-intensive and costly endeavor. Conventionally, two-dimensional (2D) or three-dimensional (3D) circulation models are developed to furnish time series velocity data, facilitating an assessment of the tidal energy resource at a given site. This paper presents a case study of tidal energy resource assessment and development at Kootznahoo Inlet, incorporating an economical 1D circulation model (DYNLET) in conjunction with a 2D version (Delft3D). The paper delineates the advantages and limitations of the 1D model, juxtaposed with the benefits and limitations inherent in the 2D approach.
Advance Technologies for Efficient Utilization of Well Slots in Offshore Platforms
Authors: Hou Xinxin , Zhang Lei , Xie Tao , Lin Hai , Liu Hailong , Liu Yuyan , Chen Kejin 
Published: April 2024

Abstract
Well slots are the most essential resource in offshore oilfield development, and how to efficiently utilize limited well slots in offshore platform instead of building new offshore platform is the key to improve the economic benefits of oil fields.
Firstly, well slot expansion technology of old offshore platform including hanging well slots inside and outside the offshore platform considering structure strength of old platform. Secondly, sidetracking new wells from old wells with low production is proposed to develop remaining oil near the old platform and sidetracking point is optimized towards deep to reduce footage. Thirdly, combined with reservoir, multilateral branch wells are drilled to improve oil drainage area and enhance oil recovery, moreover, branch bore open hole anchor and external packer are developed to hang sand control screen pipe and maintain wellbore stability instead of leaving branch hole without any sand control methods.
Well slot expansion technology has been used in old platforms, and 35% wells slots have been added to drill new wells to develop remaining oil around old platform. In old well sidetracking, advanced sidetracking tool with high build up rate reaching 120 deg/100 ft is developed and applied in many wells including T shaped well, the sidetracking points have been moved down and the overall footage have been reduced compared with conventional build up tools, and single well construction period have been reduced by 2 days. Multilateral branch wells with 1268 meters long main bore and 2 branch bores have been successfully completed with open hole anchor and external packer to hanger sand control screen pipe, and the production rate is twice as that of the original branch bore without any sand control method.
This technology has been applied in Bohai Oilfield and new platforms have been saved every year as re-utilization of well slots, which can also provide reference for other offshore oil fields.
New Opportunities in Well and Reservoir Surveillance Using Multiple Downhole Pressure Gauges in Deepwater Injector Wells
Authors: Pankaj Piyush , Romero Edgar E. , Jackson Matthew S. 
Published: April 2024

Abstract
In the recent years there has been considerable focus on value creation from downhole instrumentation within oil and gas production wells, specifically in deep water assets where cost of production logging is significant. As a result, injector wells are often overlooked from an instrumentation perspective during development of deepwater fields. As critical as reservoir sweep and pressure maintenance can be to achieving the expected ultimate recovery (EUR), monitoring the injection profile, formation damage, and fracturing through the full well life cycle is often overlooked. This paper shares a study exploring the potential surveillance benefits of deploying downhole pressure gauge arrays in injection wells.
Well, reservoir and injection data were collected for a representative offshore horizontal injection well with a stand alone screen, inflow control device (ICD) completion. Low count, pressure gauge arrays were selected as a potential alternative to fiber optics for injector performance monitoring. A calibrated pseudo steady state well model was created to evaluate gauge array design parameters against ability to measure flow. Downhole pressure gauge array measurements were evaluated against the models predicted injection behavior. Optimum number of gauges to decipher well injection flow distribution, skin build up over time, fracture creating in both longitudinal and transverse directions, and flow blockage in tubing were assessed.
An application of pressure gauge arrays was identified as a potential viable alternative to fiber optic monitoring. The use of pressure gauge arrays in injection well exhibited promising results with accuracy greater than 95% in predicting injection flow distribution. Furthermore, the predictability improves as gauge -to-gauge spacing is optimized. Additionally, localized buildup of formation skin on injectors over time was measurable with high degree of accuracy as the gauge separation was reduced. Hydraulic fractures initiated in injectors showed distinct pressure signature to identify the possible transverse or longitudinal fracture initiation. However, the location of a transverse fracture generated in the near wellbore beyond the screen was more difficult to identify due to the discrete nature of pressure gauge measurements. Well blockage and injectivity index reduction was easily detected by pressure gauges ported to measure inside of the tubing.
Currently, not many case studies exist for deepwater injection well surveillance in the literature. However, as relatively newer surveillance techniques such as fiber optics evolve, this study provides a view into a robust and cost-effective technology that could be a useful tool in solving the questions around well and reservoir surveillance for improved management and proactive response in reservoir maintenance, data handling, interpretation and implementation of insights generated.