bluuebunny/crossref_metadata_2025_split huggingface dataset:
Carbon Capture on FPSOs
Authors: Touzé L. Le , Fourrier F. , Berendsen R. , Yamamoto S. , Kamijo T. , Tanaka Y. 
Published: April 2024

Abstract
The paper presents the development of a flue gas carbon capture solution for gas turbines on FPSOs, which is the main source of GHG emissions onboard FPSOs. It addresses the design aspects, including layout and performance, together with the execution challenges, such as construction and commissioning.
Based on the technical challenges raised by low CO2 concentration gas flow treatment offshore, the overall approach has been to combine the skills and experiences of an FPSO company and a technology provider specialist. The starting point has been to evaluate the global demand in terms of power generation required onboard an FPSO, then assess the most suitable technology available with the required level of maturity to meet short-term market needs. The carbon capture plant has then been sized based on a specific gas flow associated with the power demand. A moving column study was then performed to prove the overall performance of the plant. This study provided reliable tower sizing. Tower sizing has an essential role in the carbon capture plant's performance as well as a major impact on the layout.
The main outcome of the development is that capturing CO2 from gas turbine flue gas is technically feasible offshore. The challenges are numerous; and the key challenge is the plant footprint, which has a direct consequence of the volume and characteristics of flue gas to treat. The feasibility study also showed that transposing onshore-based CO2 abatement technologies offshore is feasible. In addition, being offshore can also bring some advantages, like access to large volumes of cold water and, in some specific cases, access to CO2 reinjection capabilities. The constraints of having very large equipment on a limited area will probably drive the design by adjusting the capacity of the plant; this is a way of approaching the size of a plant that is not common in the onshore petrochemical industry. Finally, construction and commissioning will strongly influence the execution model due to the size of the plant and the utility requirements.
In summary, the study demonstrates the technical feasibility of significantly reducing CO2 emissions from FPSO operations offshore.
Accelerating the Commercialization of Marine Renewable Energy Through Parallel Deployments of Multiple Hydrokinetic Power Systems
Authors: Cahill B. G. , Davies S. E. , Johnson N. E. , Kist S. , Zarate L. , Leung P. 
Published: April 2024

Abstract
The objective of this paper is to outline how the technical validation and market uptake of marine hydrokinetic devices are being accelerated through the demonstration of the technology across multiple operating environments and use cases. This paper will describe how a single cross-flow hydrokinetic turbine design has been incorporated into a range of power systems covering multiple market applications across river and tidal operating environments. The technology has been advanced through a design and testing pathway that has spanned seventeen system deployments and has culminated in the parallel operation of six devices across four locations in the US and Canada in 2023. The paper will demonstrate how these projects have been delivered, combining internal engineering, development, and operational expertise with partnerships with communities, research organizations, regulators, and suppliers.
The paper outlines the lessons learned from the installation and operation of ongoing hydrokinetic turbine deployments at four distinct river and tidal environments across North America. It will demonstrate how the performance and survivability of the core technology are being validated across a wide range of challenging conditions, and how operations and maintenance capabilities must be scaled up to manage parallel projects safely and effectively. Furthermore, the data and operating experience generated through these installations are helping to develop the business case for the commercial application of these power systems in providing baseload renewable power to remote and island communities as well as in industrial-scale use cases. Finally, the paper will share how these projects are helping to accelerate the growth of the installed hydrokinetic device capacity in 2024 and beyond by opening up new project opportunities of greater scale and commercial impact across global markets, including demonstrations on the Mississippi River, in South America, and Europe.
Enhancing the Precision of Fatigue Analysis for Crucial Jacket Tubular Joints
Authors: Nekstad O. J. , Thomas A. P. 
Published: April 2024

Abstract
Offshore jackets and towers are examples of lightweight support structures for wind energy and oil and gas units. However, their reduced weight is obtained at the expense of increased susceptibility to fatigue failure because of their many welded connections. This study addresses the limitations of traditional analysis methods that primarily rely on parametric Stress Concentration Factors (SCFs) and basic beam theory, often leading to overly conservative outcomes, and proposes a methodology to revolutionize the fatigue analysis process by enabling the rapid creation of detailed 3D Finite Element (FE) models for tubular joints in a short time duration. The paper presents a comprehensive comparison between the advanced shell fatigue analysis and traditional beam methods, highlighting the former's superior accuracy in evaluating stress concentrations in complex joint geometries, thereby offering more precise predictions of fatigue damage. Through extensive case studies, the effectiveness of this advanced approach in accurately predicting fatigue damage in offshore jacket structures is demonstrated, showcasing its alignment with international standards like DNV-RP-C203 and significantly enhancing the precision of fatigue analysis. The study contributes to the offshore industry by improving safety and reliability, offering cost-effective design and maintenance strategies and facilitates the adoption of sophisticated analytical methods. This research offers an innovative methodology in fatigue analysis methods for offshore structures, setting a new benchmark for safer, more efficient, and technologically advanced practices in the offshore sector, thus ensuring the long-term sustainability and operational success of these crucial installations.
Emulsion Stabilized Hydrate Slurries: An Operational Flow Assurance Reality or a False Sense of Security?
Authors: Wylde Jonathan J. , Majid Ahmad A. A. , Bbosa Ben , Smith Rashod , Hernandez Oris , Asheim Colton , Patel Zubin 
Published: April 2024

Abstract
This paper provides a detailed case study on a lab-to-field strategy evaluating the use of flowline emulsions as a method of chemical-free hydrate control up to 25vol.% water cut. This is now ready to be put into successful operational practice in the deepwater production environment.
The oil in question was known to have a strong tendency to emulsify, and a detailed study of the separability of oil and water was necessary to understand the propensity for emulsions to form and more importantly break. Rheology studies were used to determine the thermal and shear influences on emulsion stability. These results better aligned the hydrate application testing performed using rocking cell and autoclave methods to determine hydrate formation under dynamic conditions and the propensity for hydrates to form at ever-increasing water cuts. Customized test protocols were required for the hydrate testing to better risk manage the nuanced aspects of hydrate formation including agglomeration amount and bedding (settling) propensity.
The emulsion testing showed a very stable and tight water-in-oil emulsion formed that didn't invert until &gt;50vol.% water cut. The emulsions were rheologically complex and very temperature and shear dependent. At typical steady state subsea conditions, significant separation was not anticipated to occur up to and beyond 25vol.% water cut. Hydrate performance testing was able to demonstrate that at shear stresses approximating the flowline, 25vol.% water cut was able to remain emulsified for the whole of the test and was not available to create a significant hydrate slurry. At 30vol.% water cut significant hydrates formed and were deemed too operationally risky to go untreated. As of this time of writing, the field is not producing significant amounts of water requiring hydrate control, however the testing enabled a risk management approach that will require no hydrate control ("do nothing") for water cuts below 25% for extended shutdowns and cold restart scenarios. Flow assurance strategies and procedures are being updated to reflect this approach.
Taking advantage of the use of naturally occurring emulsions to solve deepwater hydrate flow assurance challenges is a novel and developing technique. Successfully risk managed cases are required to be shared with the industry to drive towards a lower carbon footprint production future coupled with less chemical exposure to the environment.
Study on Sand Production in Natural Gas Hydrate During Radial Wells Depressurization Exploitation
Authors: An Youkeren , Zhang Yiqun , Wu Xiaoya , Hasan Khanjar , Du Hongxing , Hui Chengyu 
Published: April 2024

Abstract
Radial wells are recognized as a promising type of well for achieving the commercial development of natural gas hydrate (NGH). Previous research has confirmed the positive impact of radial wells on enhancing the efficiency of NGH exploitation. However, the impact of radial wells on the reservoir intensifies pressure transmission and hydrate dissociation during the hydrate extraction process, significantly increasing the risk of sand production. Furthermore, in contrast to conventional reservoirs, hydrates in the South China Sea (SCS) are primarily hosted in unconsolidated argillaceous siltstone reservoirs. These reservoirs have poor cementation and weak stability, leading to an increased risk of sand production.
This study aims to investigate the issue of sand production in radial well exploitation by constructing a three-dimensional thermal-hydrologic-mechanical-chemical coupling model based on the reservoir parameters in the SCS. The analysis focused on variations in production capacity, sand production, and stress distribution between vertical wells and radial wells during the depressurization exploitation processes. Furthermore, a sand control standard is proposed to assess the impact of sand control on radial well exploitation.
The results show that: 1) Under the present simulation conditions, the annual gas production of radial wells is increased tenfold compared to vertical wells, but the problem of sand production is more serious. 2) Stress concentrations are the most serious problems that occur during hydrate exploitation, particularly in the near wellbore and perforation sections. 3) Raising the sand control standard for radial wells can effectively alleviate sand production issues but may lead to a decrease in exploitation efficiency. In summary, this paper offers valuable insights and guidance for managing sand production and sand control in NGH exploitation through radial well depressurization.
Low-Cost Below Seabed Monitoring Solutions for Monopile Foundations
Authors: Walker William P. , Williams Ryan S. 
Published: April 2024

Abstract
Monopiles are the most common type of foundation currently used in the offshore wind industry. Operators may elect to instrument and monitor foundations to assess the system behavior or support integrity management. For monopile foundations, the region below the seabed is critical since this region sees the largest bending loads in the monopile. The offshore wind industry can benefit greatly from sub seabed measurement systems as they can provide vital information regarding structural health and provide data to optimize future designs. However, installing sensors below the seabed is a non-trivial task that can occupy significant costs to engineer and implement such systems, which is a challenge in an industry that commands low-cost solutions. This paper presents an engineering study of two sensor cover concepts designed for implementation of sub seabed monitoring on a monopile foundation. The two concepts selected are designed to be fabricated from off-the-shelf components, producing a low-cost solution to sub seabed monitoring. Furthermore, the design relies on a combination of sub-scale testing and quasi-static analysis to reduce design costs and help support a low-cost solution.
Both strength and fatigue were considered in the design. Strength analysis was performed using a finite element analysis (FEA) where a series of acceleration loads, intended to represent the acceleration spectrum that would be present during pile driving, were applied to the protection systems in a quasi-static analysis. Additionally, a fatigue analysis is performed for the bolted connections on one concept using the stresses from the FEA. Two concepts were tested via a pile driving test with a sheet pile. The pile driving process was monitored and accelerations for each blow were measured during the testing. One of the two concepts tested survived the pile driving testing with accelerations measuring up to 900g, while the other failed.
The analysis and testing performed for this design showed that the sub seabed sensing on monopile foundations can be built from low-cost steel components, given proper collaboration between with the monopile designers/fabricators and the measurement system provider. Furthermore, this work has shown that sub seabed sensing for offshore wind monopile foundations can be done in a reliable, cost-effective manner that utilizes efficient design practices and is manufactured from commercially available, low-cost materials and components. Additionally, this work serves as an enabling solution for integrity management of offshore wind farms to help reduce operation and maintenance (O&M) cost.
Innovative Method for Large Corrective Maintenance of Floating Offshore Wind Turbines
Authors: Môre A. , Cermelli C. 
Published: April 2024

Abstract
Floating offshore wind turbines (FOWT) offer unique operational and maintenance (O&M) challenges and opportunities compared to their fixed-bottom counterparts. Situated further from shore, FOWT benefit from stronger, more consistent winds, but this increased distance leads to longer travel times and harsher conditions, reducing accessibility. Traditional jack-up vessels become impractical in deeper waters. Additionally, the inherent motions of FOWT introduce complexity to maintenance strategies.
As wind turbine dimensions continue to grow, major component replacements (MCR) require heavier lifts at greater heights. The conventional MCR approach for semi-submersible FOWT is the tow-to-port strategy, which can be complex, time-consuming, and costly. Consequently, there is a growing need to explore alternative onsite options.
This article introduces a novel floating-to-floating method for FOWT MCR, developed and numerically tested using a leading software for the dynamic analysis of offshore marine systems. The component to be replaced, also referred to as "package" below, is typically first removed from the wind turbine nacelle, and a replacement part is then re-installed. The method comprises: A motion-compensated offshore crane capable of lifting components and adjusting winch length based on the package relative distance from its target on the nacelle.Horizontal control lines (tag lines) connected to the package base, passing through deflectors at the nacelle top, and linked to winches or capstans.
To ensure a safe package transfer between the offshore crane and the nacelle, relative motion should not exceed a few centimeters when the package lands onto the nacelle. Numerical analysis results confirm that this method enables accurate transfers with low tension in the tag lines.
This innovative approach promises to enhance the efficiency and safety of maintenance operations for floating offshore wind turbines, addressing the unique challenges posed by their remote locations and size.
An Integrated Wave Energy Recharging System for Autonomous Underwater Vehicles
Authors: Mundon T. R , Rosenberg B. J. , Murrillo M. 
Published: April 2024

Abstract
This work presents an energy harvesting system that can be integrated into most autonomous underwater vehicles (AUV), allowing it to operate for significantly longer periods of time, potentially indefinitely. This wave-power charging capability is achieved by integrating a retractable reaction structure that can be stowed against the body of the AUV when not in use and two rotary power takeoff elements housed inside the AUV. The technology is applicable to most AUV's; however, this study focuses on implementation within a Lockheed Martin ‘EMATT’ vehicle, a small 4 7/8" torpedo shaped AUV.
Comparison of Fatigue Damage Caused by Wave and Wind for a Semi-Submersible Wind Turbine Structure
Authors: Wang Weihua , Gao Yidi , Song Chunhui 
Published: April 2024

Abstract
Floating wind turbine structures are subjected to complex fatigue damage resources, such as wave dynamic, blade motion, turbine vibration, wind turbulence, structure vibration and so on. A study of a semi-submersible wind turbine structure has revealed that the load from wind turbine significantly affects the fatigue behavior of the structure. However, how the load is comprised and how impacts fatigue life is unknown. Lately developed fully coupled time domain global analysis are capable of getting the time history of wind turbine tower bottom load. A study is performed to analyze the load the get the components of the loads. To get fatigue life of the whole structure, a complete structure model instead of hydro model is required. Due to the complication of the fully coupled time domain structural analysis, it is required to develop a methodology for coupling wind and wave impact on the fatigue life of the structure. In this study, time domain wind turbine load is used to compute the fatigue life due to wind and spectral fatigue method is used to computer fatigue life caused by wave. Then the fatigue damages were combined and compared to give suggestions for the future floating wind turbine structures.
Long Distance Motor Control Technology of Electric Submersible Progressive Cavity Pump in Deep Well Lifting, a Case Study
Authors: Huang Shouzhi , Hao Zhongxian , Zhu Shijia , Chen Qiang 
Published: April 2024

Abstract
The electric submersible progressing cavity pump (ESPCP) lifting technology has the advantages of rod-free pipe offset wear, low energy consumption, high system efficiency and high degree of digitalization. It is suitable for heavy oil wells, sand wells, gas wells, highly deviated wells, horizontal wells, platform wells and other complex condition of producing wells. ESPCP was widely used in recent years, and nearly 1,000 wells were applied in PetroChina. However, deep well lifting has been the bottleneck that electric submersible progressing cavity pump is difficult to break through. The deepest setting depth of pump of ESPCP in China was around 2,500 meters. With the increase of the setting depth of pump, the lifting capacity of the ESPCP gradually decreases, and the failure rate also increases. The fundamental reason is that the current variable-frequency drive cannot meet the needs of long-distance motor control.
In this paper, the terminal voltage and output power loss of the motor under the conditions of different cable lengths were analyzed through experiments, and the reasons for the power shortage of the long-distance motor were summarized. A novel long distance motor control technology of ESPCP based on vector control and revised filter was developed in this paper. A new vector control model suitable for long-distance motor control was established. The angle between dq-axis and stationary coordinate was calculated based on three-phase inductance of motor to get the maximum armature current. The compensation model was built according to the load and cable loss. At the same time, the inverter voltage was increased to 1140 V, and the motor structure was optimized.
The validity of the model was verified by experiments. Through the long distance drive experiment of ESPCP with new vector control technology, the actual output power of the motor was increased by 40% compared with the formed control method. ESPCP with this new control technology was carried out in Xinjiang oilfield, and the depth of pump setting was over 3,000 meters which was the deepest record of ESPCP application in China.
This long distance motor control technology of ESPCP provides an effective method to solve the low output power caused by long cable and overload, and the setting depth and applied range of ESPCP is extended.
Subsea Innovations and Technologies in Revitalization of Deepwater Brownfields in Brazil
Authors: Campos R. C. Lancelotti , Roberto M. , Campello G. C. , Capella da Fonseca M. M. , Orlowski R. , Moreira R. H. , Anna F. R. Sant' , Santana A. B. 
Published: April 2024

AbstractThe brownfields offshore Brazil comprise over 11,000 km of subsea pipelines and risers, 700 subsea Christmas-Trees and 60 manifolds, all interconnected with more than 50 platforms. These fields offer promising investment opportunities due to enhanced reservoir knowledge and the utilization of existing production infrastructure.This paper presents a selection of subsea innovations and technologies developed to overcome the challenges associated with the revitalization, infill and subsea tieback projects of Marlim, Voador, Marlim Sul, Marlim Leste, Jubarte, Albacora, Barracuda/Caratinga, Roncador, Tartaruga Verde, and Espadarte brownfields.A brief description of the subsea systems of the above-mentioned projects is also presented, as well as the main challenges associated with each one.