bluuebunny/crossref_metadata_2025_split huggingface dataset:
External Power Supply for Ultra-Deep Water O&G Assets: Synergies, Scale Effects and Challenges
Authors: Silva Daniel Fonseca de Carvalho , Freire Ronaldo Lucas Alkmin , Borges Gilcelia Carlos , Ribeiro Leonardo da Silva , Lemos Daniel Faro do Amaral , Marinho José Mauro Teixeira , Cavaliere Carlos André Carreiro , Matheus Caio Rabello Vaz , Passarelli Fabio Menezes , Musse Ana Paula Santana , de Oliveira Ana Margarida , Guimaraes Paula Silva , Malateaux Ezequiel Costa , Prunzel Paulo Frederico , Oliveira Felipe Silva 
Published: April 2023

Abstract
A dramatic reduction of greenhouse gas emissions in offshore oil and gas production facilities in the coming decades is foreseen, which will require profound changes in offshore electrical power supply. In this paper, several scenarios comprising offshore oil & gas production facilities were analyzed in terms of fluid production curves and primary processing plants schemes, so that power and heat demand are estimated. Assuming that heat remains supplied through simple-cycle gas turbines with waste heat recovery units like existing facilities, power importing margins were determined for optimum heat recovery in a number of offshore assets. Three low-carbon external power supply options were investigated: (i) Power from shore; (ii) Offshore power generation with post-combustion carbon capture and storage (CCUS) and (iii) Floating offshore wind. Results are analyzed in terms of technical feasibility, economic indicators and emissions reduction potential. The present study consists in evaluating and comparing the LCOE (Levelized Cost of Electricity) and emissions reduction of offshore oil and gas projects with power import alternatives. Practical limitations for implementation in brownfields for each scenario are discussed when presenting the challenges that must be faced. Scenarios comprising a wide range of external power supply capacity, and consequently many power import systems, were analyzed and compared. With production units far from the coast, importing power from the national grid may require a lower LCOE than implementing a power hub with CCUS, according to the results of this study, but the required investments (CAPEX and OPEX) are substantial, especially in brownfield projects where the upgrade to external power supply would be redundant with the already existing power generation system of the offshore facility. Additionally, floating offshore wind alternative, in turn, has restrictions because of the intermittent generation and relatively low capacity factor. Nevertheless, the results present some insights regarding the intercomparison among all alternatives to large scale offshore hubs connected to multiple offshore assets. Despite external power supply alternatives requiring substantially higher costs, it is expected for these costs to reduce in the near future with standardization of the required technologies. This trend can unlock opportunities to provide energy to additional subsea Processing & boosting, which may be the key to accelerate the adoption of external and low carbon power supply of O&G assets.
How Texas Can Become the Leader in Offshore Wind in North and South America by Using New Technology and Leveraging Existing Infrastructure and Expertise
Authors: Shelley Steffen Allan , Boo Sung Youn , Luyties William H. , Griffith D. Todd 
Published: April 2023

Abstract
Large fixed and floating wind farms are planned in the US, the first of which will come on stream along the East Coast, and then possibly followed by the West Coast in deepwater. However, there are other regions in North and South America, and even the Caribbean that are rapidly aiming for offshore wind farms. One of those locations, offshore Texas, may develop ahead of the West Coast by taking advantage of the unparalleled expertise in ocean engineering in Texas gained through over 40 years of offshore oil and gas developments.
In addition, Texas has regional competitive advantages that could result in another offshore boom for the region. Texas is the leading state for onshore wind power and consequently has some highly innovative research institutions and initiatives that could further push Texas to the forefront of regional, if not global, offshore wind technology development and deployment. The additional advantages that Texas can provide to wind farm developers based on its proximity to the Caribbean and South American offshore wind markets are also presented.
As an example of innovation in Texas, the University of Texas at Dallas, DOE ARPA-E (Department of Energy Advanced Research Projects Agency – Energy) funded vertical axis wind turbine (VAWT) development is summarized (ARPA-E, 2020). While elements of VAWT technology are transferable to horizontal axis wind turbine (HAWT) technology to improve HAWT performance, more generally, the deployment of VAWTs overcomes many logistical and performance problems inherent in deploying HAWTs offshore. Such VAWT advantages are discussed.
Two cases are presented comparing HAWT versus VAWT floating wind farms. The technology and execution differences of the two cases are compared and the net present value and internal rate of return are calculated conserving the technology differences. Discussion of forthcoming additional financing opportunities is also presented to illustrate how even in low-cost electric rate markets, offshore wind can still be feasible.
Advanced Analytic Tool Development for GHG Emissions Monitoring in Well Operations
Authors: Iorio Vanessa Silvia , Farina Daniele , Racca Stefano , Dal Forno Luca , Concina Fabio 
Published: April 2023

Abstract
In the global effort to reach near-term reductions in Green-House Gas (GHG) emissions, all Energy Companies have set an integrated strategy for a low-carbon future. The decarbonization target makes evident the need to also quantify the carbon footprint of well construction activities.
The major direct emission source in Drilling and Completion (D&C) is represented by the fuel burnt by diesel generators at rig site to feed tools, machinery, and auxiliary systems. Therefore, data related to fuel consumption are fundamental to have a clear understanding of rig carbon footprint. In this framework, a dedicated GHG module was introduced within an existing real-time advanced analytic tool to unlock the possibility to track and map the CO2 equivalent emissions associated to the fuel consumption of Eni's rigs.
This tool has been designed to collect and analyze the different data sources available at the rig site, typically sensor data, recorded at high frequency (1-5 sec), and reporting data, recorded at low frequency (1-2 hrs). The data are combined, with a specific algorithm, to automatically identify the activity ongoing and its related emissions. After that, data are gathered and consolidated to make them available in headquarters in near real-time. Furthermore, the tool was also applied to a case study by comparing its outcomes with the data directly provided by a rig contractor, showing a good level of reliability and consistency. The capability to monitor GHG emissions during D&C activities allows a better understanding of their related impact. It provides useful insights to implement corrective action and tackle them promptly. Finally, operation monitoring is directly linked with its related GHG emissions allowing new types of analysis and considerations.
This integrated tool, able to recognize the most carbon-demanding activities, optimizes the process of targeting suitable solutions for GHG abatements during the well construction process. Having CO2 emissions reduction become crucial, this approach will certainly be the backbone of the transformation that Oil & Gas sector will have to undergo to reach its carbon neutrality commitments.
Dynamic High Voltage Subsea Cables and Fatigue of its Components
Authors: Johanson Audun , Gjølmesli Elisabeth 
Published: April 2023

Abstract
Subsea cables plays a pivotal role in the offshore energy space. Increased expectations considering offshore renewable power production- or electrification requirements, represents primary drivers for continued innovation of dynamic cables. Larger transmission capacity- either by increased voltage or conductor cross-sections, increase the physical footprint of cable components or introduce completely new components in a dynamic cable context- Most notably a radial water barrier. Fatigue as a failure mode becomes an increasingly relevant and critical failure mode where the relevant mechanisms, material selection and environment differentiate from prior art. The scope of this work is to investigate fatigue as a failure mode in a state-of-the art subsea cable context, as well as highlight current technology level of high voltage dynamic subsea cables.
Electrically Heat-Traced Flowline on Aerfugl Phase 2 Project -Performance and Operational Feedbacks
Authors: Guy Mencarelli , Camille Pradeilles , Pierre Reboul , Per Forbord , David Gibson , Kenneth Vullum-Bruer 
Published: April 2023

AbstractAs part of the Skarv field development strategy, the Ærfugl phase 2 project is a ~13km tie-back requiring an electrical heating flowline to provide reliable and cost-effective hydrate management.This paper will present the results of the in-field performance test and how they compare to the system intended basis of design then evaluate the operational advantages of such technical solution for an Operator.In production since November 2021, the operational feedback on the highly insulated Pipe-in-Pipe associated to the Distributed Temperature monitoring System (DTS) and data gathered during the performance test at first shutdown are used to confirm the system thermal & electrical heating performances as delivered, compare against the intended design basis, validate the operational benefits of the system in both passive and active modes for the Operator and quantify the operational gains during production shutdown.In close collaboration with the operator, the temperature monitoring data have been collected and processed to be correlated with the thermal insulation efficiency to validate the design envelop. In addition, several months of production feedback, it is demonstrated that the combination of the very efficient passive thermal insulation obtained using Izoflex in a reduced-pressure environment and a distributed temperature sensing system leads to reduced production risks and an increased operational flexibilityThe performance test data of the electrical heating system confirming the design prediction is the ultimate demonstration of the readiness of the Electrically Heat-Traced Flowline at a project scale. This is a major achievement for such technology which thanks to its improved maturity level is confirmed as playing an important role in future subsea developments to safely increase production and provide operational flexibility with low carbon emissions.This paper will show for the very first time on a sizable project the actual performance of an electrical heating pipe-in-pipe in conjunction with in-depth operational feedback on the use of a temperature monitoring system in a flowline. The associated operational gains for a particular case study are now demonstrated.
Remote Characterization of Produced Water via Subsea Multiphase Metering
Authors: Darab Mahdi , Røyset Ola-Marius Langelo , Nygaard Rune , Odai Lowestein , Singh Arvinder Paul 
Published: April 2023

Abstract
Multiphase flowmeters (MPFM) are used to measure oil, water, and gas volumetric flow rates in real time without phase separation. Field-proven MPFM play an important role in oilfield operations as the trusted flow measurements enable production optimization and flow assurance. However, accurate multiphase flow metering requires knowledge of the reservoir fluid properties. Therefore, operators require reliable methods to keep the MPFM configuration updated and representative of the production fluids. This is particularly important for subsea fields where physical access to the MPFM can be difficult.
This paper describes a successful remote water-phase characterization leading to reconfiguration of a dual-energy spectral gamma ray MPFM for an oil well in a deepwater field offshore Ghana. Reconfiguration of the MPFM was performed using data from when the well was shut in and the flowmeter venturi throat was filled with water at static flow conditions. The data was taken from Subsea Live data-driven performance service from OneSubsea (the vendor), which offers real-time data for health, operational and production insights for subsea assets. The mass attenuation coefficients for water were updated in the MPFM configuration to more representative values, determined using historical data. After the remote reconfiguration, the reconfigured MPFM demonstrated good accuracy when benchmarked against topside separator measurements, showing a proper agreement between the estimated in-situ values using historical flow metering data and the experimental measurements for both high energy and low energy water mass attenuation coefficients.
Offshore Industry and Research Community Collaborating to Enable Greater Ocean Access for Scientific Research
Authors: Olivier Blaringhem James , Woolgar Andy , Gates Andrew R. , Bishop Phil , Clare Mike , Flohr Anita , Sands Carla , Lichtschlag Anna 
Published: April 2023

Abstract:
BORA Blue Ocean Research Alliance® aims to advance scientific knowledge of the ocean through integrating science into routine offshore operations and data collection, done in parallel to commercial work and as automated as possible. This can be through integration of novel sensors, deployment of scientific research equipment or through recognising where valuable data can be derived from other operational information. To achieve this requires deep understanding of the types of work carried out by each alliance party.
BORA Blue Ocean Research Alliance® is science focussed, increasing global reach for ocean observation into areas in which Subsea7 are operating. Fundamental to the scientific value of each project is to ensure that derived data are openly accessible and aim to meet FAIR data standards (Findable, Accessible, Interoperable, Reusable), so that the findings can be re-analysed in future or contribute to wider assessments of ocean health.
Building on the blend of Subsea7's global deep-water reach and the breadth of science of NOC, BORA Blue Ocean Research Alliance® is delivering new marine research on a global scale not possible before, from shallow to deep water, expanding knowledge for the benefit of society.
Low Temperature Geothermal for Offshore Use
Authors: Furtado Ivan , Robinson Roy 
Published: April 2023

Abstract
Geothermal energy is a baseload power generation system which uses the high temperature of the deep layers below the Earth’s surface. It has traditionally relied on very high temperature wells, usually at temperatures over 180°C, but no less than 100°C (Ref 5). The largest geothermal plant in the US, The Geysers Plant in California, uses steam that is over 250°C (Ref 4). The systems are costly and available locations limited by the depth required to achieve these temperatures. Using organic Rankine cycle technology much lower temperatures can be and are used to generate electricity. Ocean Thermal Energy Conversion (OTEC) famously runs on a 20°C temperature difference, with the hot side being about 25°C and the cold side being 5°C or colder.
This paper will provide a practical design and thermodynamic analysis of a system designed to run at no more than 100°C. This is a temperature that can be encountered at a reasonable depth onshore and offshore. In the Gulf of Mexico many of the legacy reservoirs are hotter than this (Ref 6).
Offshore we will also take advantage of the immense heat sink that is the ocean. The system will utilize well derived heat and cold water to run a power cycle.
It is expected that low temperature geothermal will be a practical source for offshore baseload power. One possible use is to power oil and gas platforms, which as they transition need green energy. Unlike wind offshore geothermal will not need battery backup, and once the field has played out, geothermal can then be used to supply power to shore or other nearby platforms.
Novel/Additive Information: The system will use both novel well configurations and a novel organic Rankine cycle system for power.
Machine-Learning-Based Proxy Modelling for Geothermal Field Development Optimisation
Authors: Otchere Daniel Asante , Latiff Abdul Halim Abdul , Taki Mohamed Yassir , Dafyak Longtong Abedenego 
Published: April 2023

Abstract
More than 40 billion tonnes of CO2 are released annually, hampering climate change efforts. The goal of current research is to utilise these gases in generating energy. The oil and gas industry faces increasing expectations to clarify the implications of energy transitions for their operations and business models, reduce greenhouse gas emissions, and achieve the Paris Agreement and Glasgow Climate Pact targets. A solution is integrating machine learning and geothermal energy to optimise field development to reduce CO2 emissions while meeting energy demands.
The study area is a simulated actual field data, with three existing geothermal doublets and six exploration wells. The development plan aims to satisfy the energy demand for two locations, D1 and D2, for the next 100 years, using geothermal energy and optimising field development plans via machine learning models as surrogate models. A pseudo-geological model was developed using limited field data to identify sweet spots for further drilling. Four separate model cases were simulated using DARTS. The time-energy data from DARTS was then used to train and test several machine learning models to serve as a proxy model to optimise the best strategy to meet the energy demand. The economic model was simulated for 20 years for the selected strategy for field development.
Using an injection rate of 500 m3/day per well to validate the ML models, the best-performing model had a mean absolute error within the range of 0.6 to 1.5 MW for all the doublets. Based on the ML results, the computational power and time required for field development plan simulation were dramatically reduced, and several configurations were performed. The optimal strategy for this field comprises 7 geothermal doublets, 3 for D1 and 4 for D2. This strategy uses all available wells to avoid lost investment or excess cost when those wells are needed to complement production when decline sets in after 20 years, allowing a reliable and long-term energy supply. This strategy will achieve a net energy output of 108 MW for D2 and 82 for D1. This strategy uses machine learning energy estimation for the optimum configuration and addresses the issues of excess energy storage, uncertainty in production, and rising energy demand. The economic model was based on a fixed OPEX, an estimated Capex based on field development strategy, and an associated discount rate of 7%. The project resulted in a Levelized Cost of Energy of €11.16/MWH for 20 years whiles reducing annual CO2 emissions by about 367,000 metric tons. This study shows that geothermal energy is a crucial step toward cleaner energy. ML can speed up the energy transition by optimising geothermal field development. This research aims to reduce CO2 emissions while meeting energy needs.
The Development of a Free-Standing Integrated Riser
Authors: Bomfimsilva Carlos Terencio Pires 
Published: April 2023

Abstract
Free-standing hybrid risers (FSHR) are well established in deepwater field developments in the oil & gas industry. The major advantages foreseen for the FSHR are the possibility of safely accelerate production ramp-up and requiring significantly reduced payloads at the Floating Production Unit (FPU). This work addresses the feasibility of an optimized FSHR concept, the Free-Standing Integrated Riser (FSIR), where the pipeline is integrated to the riser by means of a transition section, which is kept in place by a multiple line mooring system, which is designed to keep the functionality and integrity of the entire riser along its lifetime. The work applies numerical analysis simulated in Orcaflex; a finite element simulation software dedicated to global analysis of risers. As part of the FSIR evaluation, screening static analysis was performed to identify the most promises configurations for the multiple line mooring system, followed by a series of dynamic analyzes to evaluate the behavior of the riser in extreme conditions. In addition, several investigations were performed to assess the functionality and the robustness of the system, including parametric studies to check for installation and dimensional tolerances, assessment of fatigue damage, and checking how the pipe sizes would impact the design. The work also provides an economic analysis to evaluate how the application of the FSIR can influence the project Net Present Value (NPV) in deepwater fields such as in the Pre-Salt developments.
As a result, the FSIR has shown to be a potential solution for deepwater developments, demonstrating significant benefits against the most conventional FSHR, due to its simplicity, eliminating the need for the rigid spool, the flex-joint at the foundation, the Pipe Line End Termination (PLET), the riser lower assembly and the stress joint at the bottom of the riser. In conclusion, the novel riser system should be more economical and safer than the traditional FSHR, being possible to obtain large savings with equipment and installation time, while keeping the same advantages of being decoupled from the FPU motions and allowing for the pre-installation of the subsea system, limiting the installation schedule risk and allowing for an accelerated production ramp-up, when compared to other traditional dynamic riser systems. Overall, this new concept should lead to a considerable increase in the NPV for the projects. It is important to highlight, however, that the availability of the technology still requires the qualification program to be completed, in order to ensure that all potential risks have been properly identified, evaluated and controlled.