bluuebunny/crossref_metadata_2025_split huggingface dataset:
Scalable Geothermal Energy Potential from Sedimentary Basins and Leveraging Oil and Gas Industry Experience: Case Studies from Texas Gulf Coast
Authors: Vivas Cesar , Salehi Saeed , Nygaard Runar , Rehg Danny 
Published: April 2023

Abstract
Geothermal energy has the potential to be a dependable source of power in the future. However, its development has mostly been limited to specific geographical areas or types of rocks. The western US has relatively high downhole temperatures compared to other regions, however, similar temperatures could be found in other regions by drilling deeper into sedimentary rocks. The oil and gas industry has developed highly efficient and cost-effective methods for drilling in sedimentary basins. The main challenge is adapting these wells for geothermal energy production. When comparing the cost per foot of drilling in typical sedimentary basins to drilling in granite or igneous rocks, there is a significant cost saving for the geothermal industry. Furthermore, techniques for hydraulic fracturing used in the oil and gas industry can also be applied to geothermal energy production.
A prospective way to increase the production of geothermal energy is to utilize known reservoir rocks with storage and flow capacity that allows water or steam cycling in sedimentary basins. These rocks have the appropriate temperature, thickness, porosity, and permeability and are located at depths that do not make the drilling costs too high for the system to be economically viable.
This study will explore the unique advantages that Texas's sedimentary basins can bring to the geothermal industry, including electricity generation and direct heat utilization. Some regions of the Texas Gulf Coast have medium-high geothermal gradients, providing the potential for geothermal energy development. Texas's numerous oil and gas wells can support geothermal direct-use projects, as demonstrated by case studies. An analysis of the levelized cost of energy using geothermal gradient data suggests that there are areas with the potential to produce geothermal power at a cost of 14 cents or less per kWh. Geothermal energy has the potential to significantly contribute to Texas's energy supply by providing a clean and renewable source of power to meet energy needs.
Estimation of Shear Wave Velocity Using Empirical, MLR, and GEP Techniques-Case Study: Kharg Island Offshore Oilfield
Authors: Zamani Ahmad Mahmoudi Mohammad , Khalilidermani Mitra , Knez Dariusz 
Published: April 2023

AbstractDetermination of the shear wave velocity, Vs, is an integral part in creation of reservoir geomechanical models. This parameter together with the compressional wave velocity and rock density are utilized to calculate the dynamic elastic moduli of the subsurface formations. In well logging, the Vs can be directly measured through the Dipole Shear Sonic Imager (DSI) logs which need special requirements and technical considerations. Therefore, many researchers have strived to develop cost-effective accurate methods for Vs estimation in the oil/gas fields. The Kharg Island offshore oilfields, located in the Persian Gulf, consist of a giant limestone reservoir called Asmari formation. In the past, numerous studies were conducted to develop mathematical relations for Vs prediction in the Asmari reservoir; however those relations were not capable of estimating the Vs values correctly. In this research, the well logging data related to a vertical offshore well was utilized to develop three mathematical relations for Vs estimation in the Asmari formation. To do this, linear regression (LR), Multivariate Regression (MLR), and Gene Expression Programing (GEP) methods were applied. Moreover, the accuracy of those relations was compared with some available empirical correlations for Vs prediction in limestone rocks. Comparing the results of those data-driven equations with the empirical equations illustrated that the results of the GEP method are more accurate than other equations. Moreover, the Pickett empirical correlation was found to be more suitable than other empirical correlations for Vs estimation in the Asmari reservoir. The methodology applied in this research is a reliable procedure to estimate the Vs in the study area as well as other geologically similar oil reservoirs. Such an application leads to generation of robust geomechanical models increasing the project success and oilfield development progression.
Understanding the Gulf Ocean System Program: Informing Stakeholders and Improving Prediction of the Loop Current System Using Advanced Observational and Numerical Tools
Authors: Knap Anthony , DiMarco Steven , Glenn Scott , Ramos Rafael , Magnell Bruce , Salas David 
Published: April 2023

Abstract
Objectives/Scope: This paper describes a program funded by the National Academy of Sciences, Engineering and Medicine (NASEM) that follows up on 2 (3-year) programs to better predict the behavior of the Gulf Loop Current and its associated eddies, which in some years create havoc to Offshore Technology Industries and activities in the Northern Gulf of Mexico. The aim is to inform and integrate with Stakeholders for new and better products and agreed metrics to provide better tools for the end-users in the Gulf of Mexico. In recent years, 2015 and 2021 there were significant ocean current extremes that had major effects on the offshore industry which were difficult to predict and caused huge financial losses to offshore operations in the Northern Gulf of Mexico.
Methods, Procedures, Process: Using data from remote autonomous vehicles such as surface drifters, profiling floats, ocean buoyancy gliders, wave powered vehicles, fixed bottom moored acoustic systems, a Topographic Rossby Wave array and a series of coastal fixed High Frequency radars new models will be developed to predict Loop current dynamics, eddy shedding and reabsorption. In addition, data collected will be used to determine upper ocean heat content and its role in prediction of hurricane intensity forecasts. The program has a strong group of Private/Public stakeholders and we are hoping to get wider involvement in this program to deliver the best and most timely information to end-users in the Northern Gulf of Mexico.
Results, Observations, Conclusions: In total NASEM has funded a $40 million research program that will improve prediction, improve human well-being and improve offshore safety, and that the program seeks to understand (in this context) what the end user community needs are, to provide the foundation for continued dialogue and to provide a model for future private-public partnerships between scientists, agencies, and industry.
Novel/Additive Information: We believe that this program is unique as it relies on the involvement of industry and agency stakeholders at the beginning of the program so the observing systems and models can be co-designed and tailored to the recipient needs, not the other way around with has generally been the norm in the past.
Relative Viscosity Model for Water-In-Oil Emulsion in Electrical Submersible Pumps: Comparing the ESP Head in a Real Scenario
Authors: Bulgarelli Natan Augusto Vieira , da Silva Lucas Rodrigues Guedes , Biazussi Jorge Luiz , Monte Verde William , Melchuna Aline , Arinelli Lara , Silveira Thaís Márcia , Castro Marcelo Souza de 
Published: April 2023

Abstract
Emulsions are common during oil production, and this is the case of the Peregrino field, e.g. . In several fields, oil and reservoir fluids can be produced through Electrical Submersible Pumps (ESP) and the formation of emulsion affects the ESP system, its run life, and the production itself. The viscosity increase due to emulsion formation severely hampers the ESP performance, requiring an increase in energy consumption on the platform to keep the same production rate. This work presents an initial validation of the model proposed by Bulgarelli (2021) to predict the water-in-oil emulsion effective viscosity within the ESP and its impact on lift capacity. The model can aid the design of the ESP system and can be used as a flow rate estimation tool during ESP production. The initial validation was performed using data from water-in-oil emulsion production of the two wells (A and B) in the Peregrino field, which use two different ESP models. The validation was divided into two parts: the first corresponds to Technology Readiness Level (TRL) 3 and the second, TRL 4, according to ISO 20815:2018. Firstly, well tests data were used to calibrate and test the model for initial validation of the TRL 3. Operation data of these two wells were then used for the initial validation of the TRL 4 in the second part. In the first step, measured and predicted ESP head were compared. Mean Absolute Percentage Errors (MAPE) of 3.6% and 0.8% were obtained for Wells A and B, respectively. In the second part, both the measured and predicted ESP dimensionless head and the measured and predicted differential pressure were compared. From these comparisons, promising results were observed for both wells' operations. However, more oil data field is necessary to complete the TRL 3 and TRL 4 validation.
Using the Pugh Method to Select a Polymetallic Nodule Vertical Transport System
Authors: Barr Aaron M 
Published: April 2023

Abstract
On the sea floor of specific deep ocean environments lie prolific amounts of polymetallic nodules that contain minerals critical to meeting the future energy demands of a growing worldwide population. Polymetallic nodules rich in manganese, nickel, and cobalt spread over millions of square kilometers of abyssal seabed and contain the minerals needed for future energy storage demands. The offshore oil and gas industry seeks to participate in the energy expansion by leveraging its deepwater experience to harvest these nodules. The knowledge and wisdom gained from decades of operating offshore provides significant insight into the development and implementation of the technology needed to address the challenges of deep sea nodule harvesting.
The authors describe a design selection tool based on the methods described by Stuart Pugh to select a polymetallic nodule Vertical Transport System. Stuart Pugh, known for his work in product design and development, introduced the Pugh Method in the 1980s. The Pugh Method is a structured and integrated process applied to design development including concept generation, evaluation, and selection. The Vertical Transport System design processes uses the Pugh Method to recommend a candidate design. The evaluation step uses a two groups of company experts who present the concepts (the team), and collectively evaluate (the group) and recommend the best design concept for further development. We apply the method to the case of deep sea mineral recovery operations specifically the design of the Vertical Transportation System. First, the authors introduce the Pugh Method tool, how it works, and how it applies to this specific case. We describe how risks and rewards relate to each selection characteristic used to evaluate the Vertical Transport System concepts. Further, we talk about team selection and the points to consider when assembling the right team to achieve credible results. Next, we describe each concept identifying and recognizing the various technical, operational, and economic selection characteristics, such as size, power consumption, reliability, availability, etc. Finally, we evaluate each concept against the different selection characteristics and discuss the results. The paper concludes with a robust process flow chart describing the selection method for a Vertical Transport System.
Cost-Benefit Analysis and Comparisons for Different Offshore Wind Energy Transmisision Systems
Authors: Silva-Rodriguez Jesus Angel , Lu Jin , Li Xingpeng 
Published: April 2023

Abstract
This paper investigates how to efficiently and economically deliver offshore energy generated by offshore wind turbines to onshore. Both power cables and hydrogen energy facilities are analyzed. Each method is examined with the associated proposed optimal sizing model. A cost-benefit analysis is conducted, and these methods are compared under different scenarios. Three long-distance energy transmission methods are proposed to transmit offshore energy onshore, considering the capital/operation costs for related energy conversion and transmission facilities. The first method that only deploys power cables is a benchmark method. The other two methods utilize a hydrogen supercenter (HSC) and transmit offshore energy to an onshore substation through hydrogen pipelines. For the second method, offshore wind power is distributed to the HSC and then converted into hydrogen using electrolyzers placed at the HSC. For the third method, electrolyzers are placed at offshore wind farms connected to HSC with low-pressure hydrogen pipelines. An offshore scenario including three wind farms located in the Gulf of Mexico and one onshore substation is used as the base test case. Numerical simulations are conducted over a planning period of 30 years using the proposed optimization models for each method separately. Simulation results show that the proposed hydrogen-based methods can effectively transmit offshore energy to the onshore substation. The distances between the wind farms can influence the selection and configuration of the offshore wind energy system. Moreover, the proposed study analyzes the cost and benefits for various systems with different energy carriers. It can also suggest which method could be the best candidate for offshore energy delivery system under which scenario and demonstrate a promising future for offshore wind power generation.
Offshore CCS: Addressing Current Barriers for Storage Implementation in Geological Formations
Authors: Araujo de Itriago Yani Carolina , Swearingen Jerry Wayne 
Published: April 2023

Abstract
Carbon Capture and Storage (CCS) has long been considered as a potentially means for reducing greenhouse gas emissions from carbon-intense industrial and power generation sources. Over the last few years, there has been intense discussion about the implementation and massification of CCS as a key technology to achieve the Net Zero goal in the decarbonization era. However, the number of projects implemented globally strictly for CO2 storage is relatively small compared to CO2 utilization schemes such as Enhanced Oil Recovery (EOR) programs. This is due to the challenges faced when using geological formations only as a storage vehicle for CO2. Therefore, it is necessary to understand the factors, in addition to economic constraints, that have slowed the massification of the process, especially in offshore storage implementation.
To identify the key factors for a successful implementation of an offshore CCS project, a critical analysis of 42 offshore CSS projects in different stages together with a survey using professional networks were performed. The study started with the identification of key projects scheduled/planned or in the implementation stage worldwide, followed by the review of available technical and economic data, the status of project implementation, from permitting to field development, and finally an analysis of the collected data from the survey.
From the analysis, key factors to implement CCS offshore were identified and discussed. High costs, complex and non-standardized regulations, and lack of governmental incentives in many countries are key factors in lack of offshore CCS implementation. CCS solutions are available currently for onshore projects, but solutions for pipeline or commercial vessel transport CO2 are still being tested with an implementation expected in the near future.
In-depth characterization of the geological formation planned for storage is critical, therefore advanced tools and techniques are required. It is necessary to validate existing models and simulation models for offshore storage and to develop new tools for low-cost monitoring systems. Critical factors for offshore CCS implementation include the identification and development of technologies to reduce operative costs; development of professional skills for field implementation; use of digital technology to improve data processing; improvement of exiting offshore infrastructure; and the engagement of public and private sectors to reduce the timeline for CSS offshore implementation. Based on the current status of CCS projects, actions to close the existing barriers and minimize risks for offshore implementation are recommended.
This paper offers a critical analysis of the requirements for offshore CCS implementation including an overview of projects currently in operation and projects in planning phase along with a technical assessment of the barriers that make offshore CCS projects less advantageous in industry.
Small Deformation Finite Element Analysis of Spudcan Penetration in Multi-Layered Soil
Authors: Radwan Ahmed M. , El-Araby Ibrahim A. , Tolba Ehab R. , El-Gendy Mohmaed M. 
Published: April 2023

Abstract
Using the press-replace technique, a recently developed finite element method depending on the criteria of the small deformation analysis SDA, to investigate the soil-foundation interaction of the Jack-Up rig with Spudcan during its proceeding to achieve stability installation in Multi-Layered soil. The analysis has been implemented and compared with previously published cases, which has been done experimentally and by using large deformation finite element analysis.
The Press-Replace technique PRT is mainly has been developed able to capture the Spudcan proceeding through the multi-layered soil specifically in cases of penetrating through soft soils by simulating the possible squeezing accompanied by the back-flow phenomenon, which happens for the soft soil during the installation. The considered analysis criteria have been explicated. The results provided an effective expectation of the soil-structure interaction validated by the previous experimental and numerical results. Depending on the detailed analysis steps provided, engineers and researchers can use it to make the needed analysis for similar case studies.
The small deformation analysis SDA has been operated on six cases of multi-layered soils and compared to the previous experimental and numerical results. The variety of investigated cases was depending on the type of upper layered, either it was a soft to moderate clay layer or a sand layer. The two main criteria have been considered in the current analysis, which is the backflow of clay and the back-fill of sand. As the analysis theory depends mainly on the geometry update, the simulation steps of these two criteria have been provided in detail. That control has been applied, by observing the soil movement behavior of the previous experimental outcomes. Four cases with upper clay soil and other two cases with upper sand layers have been investigated and compared to previous experimental and numerical results. By controlling these two states of the upper soil layer, it can be obtained the different simulation steps in the analysis in the condition of the existing upper layer is sand or clay. The analysis provided shows a good comparison of stability depth to the previous results. Furthermore, it gives a very close evaluation behavior to the previous experimental results.
This approach numerical method provides a tool for the engineers to use the Press-Replace technique PRT, which is a smooth and fast numerical technique compared to the other numerical methods, to investigate and obtain the Spudcan penetration through similar cases of multi-layered soil.
Comparison of Decarbonization Pathways for Offshore Platforms: Technology Solutions to Address Key Implementation Challenges
Authors: Araujo Fresky Mariela G. , Araujo de Itriago Yani Carolina 
Published: April 2023

Abstract
Most companies to date have adopted GHG emission targets in an effort to limit global warming well below 2 °C above pre-industrial levels, and 2020 estimations forecast a decrease of about 1/3 of emissions from O&G activities by 2050. It is also foreseen that regulations with economic impact on emissions from hydrocarbon production will be progressively adopted. This is triggering oil and gas (O&G) attention to find faster and economic ways to decarbonize while maintaining operational performance. Several types of initiatives are being considered including the reduction of flaring and venting, mitigation of methane leaks, increasing efficiency in energy use, use of renewable energy, and electrification of processes, in combination with the use of digital tools, and advanced monitoring to optimize performance.
In this work we focus on a comparison of different decarbonization pathways for an offshore platform. It is assumed that the platform is already in place and in operation, and that the industry is already taking the required actions to reduce flaring and venting and mitigating methane leaks. The analysis starts by identifying the major contributors to the GHG emissions from the platform, which in this case is the power system, followed by fluid related processes like compression, separation, heating for transportation, and other associated operations. Public data from international energy agencies indicates that approximately 16 TWh/year is used to power offshore oil and gas platforms globally. We analyze the following five decarbonization pathways: a) improved energy use - decreasing the energy demand of the processes running on the platform and associated operations, b) increasing the efficiency of the power generation source, c) changing the nature of power source (renewable – wind, solar, wave, hybrid systems), d) implementing carbon capture units, and e) electrifying the facility (partial/full electrification cases).
The analysis includes a comparison of promising concepts under each of the proposed pathways and summarize the challenges and opportunities offshore O&G operators have to implement them. Some of the alternatives are based on technology already used in the oil and gas industry, or in other industries, while in some others the technology is still under development. Reference is made to novel technology with potential to address the identified challenges for the different pathway options. We use a simplified metric system to highlight the most effective solutions according to location of the platform and its distance to shore. A discussion of what we will be needed for such pathways to be feasible is also presented.