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Journal articles on the topic 'Enhanced geothermal systems'

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Author: Grafiati

Published: 10 December 2022

Last updated: 28 January 2023

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1

Sircar, Anirbid, Krishna Solanki, Namrata Bist, and Kriti Yadav. "Enhanced Geothermal Systems – Promises and Challenges." International Journal of Renewable Energy Development 11, no. 2 (December 1, 2021): 333–46. http://dx.doi.org/10.14710/ijred.2022.42545.

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Geothermal energy plays a very important role in the energy basket of the world. However, understanding the geothermal hotspots and exploiting the same from deep reservoirs, by using advanced drilling technologies, is a key challenge. This study focuses on reservoirs at a depth greater than 3 km and temperatures more than 150°C. These resources are qualified as Enhanced Geothermal System (EGS). Artificially induced technologies are employed to enhance the reservoir permeability and fluid saturation. The present study concentrates on EGS resources, their types, technologies employed to extract energy and their applications in improving power generation. Studies on fracture stimulation using hydraulic fracturing and hydro shearing are also evaluated. The associated micro-seismic events and control measures for the same are discussed in this study. Various simulators for reservoir characterization and description are also analyzed and presented. Controlled fluid injection and super critical CO2 as heat transmission fluid are described for the benefit of the readers. The advantages of using CO2 over water and its role in reducing the carbon footprint are brought out in this paper for further studies.

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2

Olasolo, P., M. C. Juárez, M. P. Morales, Sebastiano D´Amico, and I. A. Liarte. "Enhanced geothermal systems (EGS): A review." Renewable and Sustainable Energy Reviews 56 (April 2016): 133–44. http://dx.doi.org/10.1016/j.rser.2015.11.031.

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3

Wood, Warren W. "Enhanced Geothermal Systems: An Opportunity for Hydrogeology." Ground Water 47, no. 6 (November 2009): 751. http://dx.doi.org/10.1111/j.1745-6584.2009.00573.x.

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4

Majer, Ernest L., Roy Baria, Mitch Stark, Stephen Oates, Julian Bommer, Bill Smith, and Hiroshi Asanuma. "Induced seismicity associated with Enhanced Geothermal Systems." Geothermics 36, no. 3 (June 2007): 185–222. http://dx.doi.org/10.1016/j.geothermics.2007.03.003.

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5

Lee, Junbeum, and Eunhyea Chung. "Geochemical Effect of Geothermal Water Flushing during Enhanced Geothermal Systems Operation." Journal of the Korean Society of Mineral and Energy Resources Engineers 58, no. 3 (June 1, 2021): 205–14. http://dx.doi.org/10.32390/ksmer.2021.58.3.205.

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6

Feng, Chao Yin. "Enhanced Geothermal Systems Projects and its Potential for Carbon Storage." Advanced Materials Research 732-733 (August 2013): 109–15. http://dx.doi.org/10.4028/www.scientific.net/amr.732-733.109.

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Enhanced Geothermal Systems represent a series of technology, which use engineering methods to improve the performance of geothermal power plant. In some geothermal fields, the rocks are in high temperature but a low permeability, or the subsurface water is scarce. In these geological conditions, cool water was injected into the geothermal wells to fracture the tight rock and create man-made reservoir for thermal exploitation. Furthermore, these engineering methods can be utilized to improve the productivity of pre-existing hydrothermal power plants. To save water and treat the global warming, using carbon dioxide instead of water as working fluid was proposed. Numerical simulation reveals that the carbon dioxide has numerous advantages over water as working fluid in the heat mining process. The precipitation caused by carbon dioxide will restore part of carbon dioxide in the rock and reduce the micro-seismicity risk.

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7

Raos, Ilak, Rajšl, Bilić, and Trullenque. "Multiple-Criteria Decision-Making for Assessing the Enhanced Geothermal Systems." Energies 12, no. 9 (April 26, 2019): 1597. http://dx.doi.org/10.3390/en12091597.

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This paper presents the main features of a multiple-criteria decision-making tool for economic and environmental assessment of enhanced geothermal systems projects. The presented holistic approach takes into account important influencing factors such as technical specifications, geological characteristics, spatial data, energy and heat prices, and social and environmental impact. The multiple-criteria decision-making approach uses a weighted decision matrix for evaluating different enhanced geothermal systems alternatives based on a set of criterions which are defined and presented in this paper. The paper, defines and quantifies new criterions for assessing enhanced geothermal systems for a particular site. For evaluation of the relative importance of each criterion in decision making, the weight is associated with each of the listed criterions. The different scenarios of end-use applications are tested in the case study. Finally, in the case study, the data and statistics are collected from real geothermal plants. The case study provides results for several scenarios and the sensitivity analysis based on which the approach is validated. The proposed method is expected to be of great interest to investors and decision makers as it enables better risk mitigation.

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8

Messervey, Thomas, Marco Calderoni, Angel Font, Mikel Borras, Ray Sterling, David Martin, and Zia Lennard. "Introducing GEOFIT: Cost-Effective Enhanced Geothermal Systems for Energy Efficient Building Retrofitting." Proceedings 2, no. 15 (September 21, 2018): 557. http://dx.doi.org/10.3390/proceedings2150557.

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GEOFIT, “Deployment of novel GEOthermal systems, technologies and tools for energy efficient building retrofitting,” is a recently launched 4-year H2020 project funded by the Innovation and Networks Executive Agency (INEA) under the call topic LCE-17-2017: Easier to install and more efficient geothermal systems for retrofitting buildings. GEOFIT is a part of INEA’s Energy Portfolio Low Carbon Economy (LCE), Renewable Energy Technologies (RET) and brings together 24 partners from 10 European countries to work on the development of novel and smart shallow geothermal systems. This paper introduces the project.

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9

Fairley, J. P., S. E. Ingebritsen, and R. K. Podgorney. "Challenges for Numerical Modeling of Enhanced Geothermal Systems." Ground Water 48, no. 4 (December 15, 2009): 482–83. http://dx.doi.org/10.1111/j.1745-6584.2010.00716.x.

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10

Karvounis, D. C., and P. Jenny. "Adaptive Hierarchical Fracture Model for Enhanced Geothermal Systems." Multiscale Modeling & Simulation 14, no. 1 (January 2016): 207–31. http://dx.doi.org/10.1137/140983987.

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11

Kraft, Toni, Paul Martin Mai, Stefan Wiemer, Nicholas Deichmann, Johannes Ripperger, Philipp Kästli, Corinne Bachmann, Donat Fäh, Jochen Wössner, and Domenico Giardini. "Enhanced Geothermal Systems: Mitigating Risk in Urban Areas." Eos, Transactions American Geophysical Union 90, no. 32 (2009): 273. http://dx.doi.org/10.1029/2009eo320001.

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12

Xu, Chaoshui, and Peter A. Dowd. "Stochastic Fracture Propagation Modelling for Enhanced Geothermal Systems." Mathematical Geosciences 46, no. 6 (June 5, 2014): 665–90. http://dx.doi.org/10.1007/s11004-014-9542-1.

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13

Hofmann, Hannes, Simon Weides, Tayfun Babadagli, Günter Zimmermann, Inga Moeck, Jacek Majorowicz, and Martyn Unsworth. "Potential for enhanced geothermal systems in Alberta, Canada." Energy 69 (May 2014): 578–91. http://dx.doi.org/10.1016/j.energy.2014.03.053.

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14

Martin, Samuel Peter, Alexander Richmond Perry, and Kirill Lushnikov. "An analysis of thermodynamic properties in both traditional and enhanced geothermal systems to compare thermal efficiencies." PAM Review Energy Science & Technology 4 (June 5, 2017): 103–20. http://dx.doi.org/10.5130/pamr.v4i0.1446.

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This meta-study draws upon previous research on both Enhanced Geothermal Systems (EGS) and traditional geothermal systems (GS), using these findings to compare and investigate the thermal efficiency of each system. Efficiency calculations include reservoir enthalpy, maximum drilling well temperature, power output (per unit mass of liquid) and mass flow rate of these systems to determine whether EGS’s are viable as an alternative, more readily available renewable energy source. This meta-study suggests that EGS are more viable than naturally occurring GS in the context of future geothermal energy production as they perform with a similar average efficiency of 10-15% and, in addition, can be used in a wider range of geothermal environments.

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15

Menberg, Kathrin, Stephan Pfister, Philipp Blum, and Peter Bayer. "A matter of meters: state of the art in the life cycle assessment of enhanced geothermal systems." Energy & Environmental Science 9, no. 9 (2016): 2720–43. http://dx.doi.org/10.1039/c6ee01043a.

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16

Tester, Jefferson W., Brian J. Anderson, Anthony S. Batchelor, David D. Blackwell, Ronald DiPippo, Elisabeth M. Drake, John Garnish, et al. "Impact of enhanced geothermal systems on US energy supply in the twenty-first century." Philosophical Transactions of the Royal Society A: Mathematical, Physical and Engineering Sciences 365, no. 1853 (February 2007): 1057–94. http://dx.doi.org/10.1098/rsta.2006.1964.

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Recent national focus on the value of increasing US supplies of indigenous renewable energy underscores the need for re-evaluating all alternatives, particularly those that are large and well distributed nationally. A panel was assembled in September 2005 to evaluate the technical and economic feasibility of geothermal becoming a major supplier of primary energy for US base-load generation capacity by 2050. Primary energy produced from both conventional hydrothermal and enhanced (or engineered) geothermal systems (EGS) was considered on a national scale. This paper summarizes the work of the panel which appears in complete form in a 2006 MIT report, ‘The future of geothermal energy’ parts 1 and 2. In the analysis, a comprehensive national assessment of US geothermal resources, evaluation of drilling and reservoir technologies and economic modelling was carried out. The methodologies employed to estimate geologic heat flow for a range of geothermal resources were utilized to provide detailed quantitative projections of the EGS resource base for the USA. Thirty years of field testing worldwide was evaluated to identify the remaining technology needs with respect to drilling and completing wells, stimulating EGS reservoirs and converting geothermal heat to electricity in surface power and energy recovery systems. Economic modelling was used to develop long-term projections of EGS in the USA for supplying electricity and thermal energy. Sensitivities to capital costs for drilling, stimulation and power plant construction, and financial factors, learning curve estimates, and uncertainties and risks were considered.

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17

Budiono, Andres, Suyitno Suyitno, Imron Rosyadi, Afif Faishal, and Albert Xaverio Ilyas. "A Systematic Review of the Design and Heat Transfer Performance of Enhanced Closed-Loop Geothermal Systems." Energies 15, no. 3 (January 20, 2022): 742. http://dx.doi.org/10.3390/en15030742.

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Geothermal energy is one of the primary sources of clean electricity generation as the world transitions away from fossil fuels. In comparison to enhanced geothermal methods based on artificial fracturing, closed-loop geothermal systems (CLGSs) avoid seismicity-induced risk, are independent of reservoir permeability, and do not require the direct interaction between the fluid and the geothermal reservoir. In recent years, the development of CLGS technologies that offer high energy efficiencies has been explored. Research on coaxial closed-loop geothermal systems (CCLGS) and U-shaped closed-loop geothermal system (UCLGS) systems were reviewed in this paper. These studies were categorized based on their design, modeling methods, and heat transfer performance. It was found that UCLGSs had superior heat transfer performances compared to CCLGS. In addition, UCLGSs that utilized CO2 as a working fluid were found to be promising technologies that could help in addressing the future challenges associated with zero-emission compliance and green energy demand. Further research to improve the heat transfer performance of CLGS, especially with regards to improvements in wellbore layout, equipment sizing, and its integration with CO2 capture technologies is critical to ensuring the feasibility of this technology in the future.

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18

KONG, Yanlong, Sheng PAN, Yaqian REN, Weizun ZHANG, Ke WANG, Guangzheng JIANG, Yuanzhi CHENG, et al. "Catalog of Enhanced Geothermal Systems based on Heat Sources." Acta Geologica Sinica - English Edition 95, no. 6 (December 2021): 1882–91. http://dx.doi.org/10.1111/1755-6724.14876.

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19

Bächler, D., and T. Kohl. "Coupled thermal-hydraulic-chemical modelling of enhanced geothermal systems." Geophysical Journal International 161, no. 2 (May 2005): 533–48. http://dx.doi.org/10.1111/j.1365-246x.2005.02497.x.

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20

Majorowicz, Jacek, and Stephen E. Grasby. "High Potential Regions for Enhanced Geothermal Systems in Canada." Natural Resources Research 19, no. 3 (May 8, 2010): 177–88. http://dx.doi.org/10.1007/s11053-010-9119-8.

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21

McClure, Mark W., and Roland N. Horne. "An investigation of stimulation mechanisms in Enhanced Geothermal Systems." International Journal of Rock Mechanics and Mining Sciences 72 (December 2014): 242–60. http://dx.doi.org/10.1016/j.ijrmms.2014.07.011.

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22

Zuo and Weijermars. "Longevity of Enhanced Geothermal Systems with Brine Circulation in Hydraulically Fractured Hydrocarbon Wells." Fluids 4, no. 2 (April 1, 2019): 63. http://dx.doi.org/10.3390/fluids4020063.

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A simple, semi-analytical heat extraction model is presented for hydraulically fractured dry reservoirs containing two subparallel horizontal wells, connected by a horizontal fracture channel, using injected brine as the working fluid. Heat equations are used to quantify the heat conduction between fracture walls and circulating brine. The brine temperature profiles are calculated for different combinations of fracture widths, working fluid circulation rates, and initial fracture wall temperatures. The longevity of the geothermal heat extraction process is assessed for a range of working fluid injection rates. Importantly, dry geothermal reservoirs will not recharge heat by the geothermal flux on the time scale of any commercial heat extraction project. A production plan is proposed, with periodic brine circulation maintained in a diurnal schedule with 8 h active production alternating with 16 h of pump switched off. A quasi-steady state is achieved after both the brine temperature and rock temperature converge to a limit state allowing fracture-wall reheating by conduction from the rock interior in the diurnal production schedule. The results of this study could serve as a fast tool for assisting the planning phase of geothermal reservoir design as well as for operational monitoring and management.

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23

He, Yujiang, and Xianbiao Bu. "Performance of Hybrid Single Well Enhanced Geothermal System and Solar Energy for Buildings Heating." Energies 13, no. 10 (May 14, 2020): 2473. http://dx.doi.org/10.3390/en13102473.

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The energy reserves in hot dry rock and hydrothermal systems are abundant in China, however, the developed resources are far below the potential estimates due to immature technology of enhanced geothermal system (EGS) and scattered resources of hydrothermal systems. To circumvent these problems and reduce the thermal resistance of rocks, here a shallow depth enhanced geothermal system (SDEGS) is proposed, which can be implemented by fracturing the hydrothermal system. We find that, the service life for SDEGS is 14 years with heat output of 4521.1 kW. To extend service life, the hybrid SDEGS and solar energy heating system is proposed with 10,000 m2 solar collectors installed to store heat into geothermal reservoir. The service life of the hybrid heating system is 35 years with geothermal heat output of 4653.78 kW. The novelty of the present work is that the hybrid heating system can solve the unstable and discontinuous problems of solar energy without building additional back-up sources or seasonal storage equipment, and the geothermal thermal output can be adjusted easily to meet the demand of building thermal loads varying with outside temperature.

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24

Kehrer, Peter, Jens Orzol, Reinhard Jung, Reiner Jatho, and Ralf Junker. "The GeneSys project a contribution of GEOZENTRUM Hannover to the development of Enhanced Geothermal Systems (EGS)." Zeitschrift der Deutschen Gesellschaft für Geowissenschaften 158, no. 1 (January 1, 2007): 119–32. http://dx.doi.org/10.1127/1860-1804/2007/0158-0119.

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25

Palacio-Villa, Maria Alejandra, Daniela Blessent, Jacqueline López-Sánchez, and David Moreno. "Sistemas geotérmicos mejorados: revisión y análisis de casos de estudio." Revista Boletín de Geología 42, no. 1 (January 1, 2020): 101–18. http://dx.doi.org/10.18273/revbol.v42n1-2020006.

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En este artículo se hace una revisión bibliográfica de las características de los EGS, fuentes de energía limpia que prometen ser una alternativa para enfrentar los problemas relacionados con el calentamiento global ocasionados por el uso de combustibles fósiles como el petróleo y el gas natural. Actualmente en Colombia los sistemas geotérmicos de interés son de tipo hidrotermal, por lo que no hay EGS planificados aún, sin embargo, este artículo pretende ser una introducción para el lector interesado en los EGS y ser referencia a futuros proyectos desarrollados en el territorio nacional, describiendo los lugares del mundo más significativos donde se ha hecho uso de esta técnica, junto con su percepción social e impactos asociados. Además, busca analizar las diferencias entre la estimulación hidráulica en los EGS y el fracking utilizado para la extracción de gas de esquisto

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26

Gee, Bruce, Robert Gracie, and Maurice B. Dusseault. "Multiscale short-circuiting mechanisms in multiple fracture enhanced geothermal systems." Geothermics 94 (July 2021): 102094. http://dx.doi.org/10.1016/j.geothermics.2021.102094.

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27

Gischig, V., S. Wiemer, and A. Alcolea. "Balancing reservoir creation and seismic hazard in enhanced geothermal systems." Geophysical Journal International 198, no. 3 (July 16, 2014): 1585–98. http://dx.doi.org/10.1093/gji/ggu221.

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28

Nummedal, Dag, Gary Isaksen, and Peter Malin. "2011 Napa Hedberg Research Conference report on enhanced geothermal systems." AAPG Bulletin 97, no. 3 (March 2013): 413–20. http://dx.doi.org/10.1306/07111212112.

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29

Asai, Pranay, Palash Panja, John McLennan, and Joseph Moore. "Efficient workflow for simulation of multifractured enhanced geothermal systems (EGS)." Renewable Energy 131 (February 2019): 763–77. http://dx.doi.org/10.1016/j.renene.2018.07.074.

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30

Finsterle, Stefan, Yingqi Zhang, Lehua Pan, Patrick Dobson, and Ken Oglesby. "Microhole arrays for improved heat mining from enhanced geothermal systems." Geothermics 47 (July 2013): 104–15. http://dx.doi.org/10.1016/j.geothermics.2013.03.001.

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31

Shao, Hongbo, Senthil Kabilan, Sean Stephens, Niraj Suresh, Anthon N. Beck, Tamas Varga, Paul F. Martin, et al. "Environmentally friendly, rheoreversible, hydraulic-fracturing fluids for enhanced geothermal systems." Geothermics 58 (November 2015): 22–31. http://dx.doi.org/10.1016/j.geothermics.2015.07.010.

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32

Gan, Quan, and Qinghua Lei. "Induced fault reactivation by thermal perturbation in enhanced geothermal systems." Geothermics 86 (July 2020): 101814. http://dx.doi.org/10.1016/j.geothermics.2020.101814.

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33

Xu, Chaoshui, Peter Alan Dowd, and Zhao Feng Tian. "A simplified coupled hydro-thermal model for enhanced geothermal systems." Applied Energy 140 (February 2015): 135–45. http://dx.doi.org/10.1016/j.apenergy.2014.11.050.

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34

Yasin, Qamar, Mariusz Majdański, Rizwan Sarwar Awan, and Naser Golsanami. "An Analytical Hierarchy-Based Method for Quantifying Hydraulic Fracturing Stimulation to Improve Geothermal Well Productivity." Energies 15, no. 19 (October 7, 2022): 7368. http://dx.doi.org/10.3390/en15197368.

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Hydraulic fracturing (HF) has been used for years to enhance oil and gas production from conventional and unconventional reservoirs. HF in enhanced geothermal systems (EGS) has become increasingly common in recent years. In EGS, hydraulic fracturing creates a geothermal collector in impermeable or low-permeable hot dry rocks. Artificial fracture networks in the collector allow for a continuous flow of fluid in a loop connecting at least two wells (injector and producer). However, it is challenging to assess the fracability of geothermal reservoirs for EGS. Consequently, it is necessary to design a method that considers multiple parameters when evaluating the potential of geothermal development. This study proposes an improved fracability index model (FI) based on the influences of fracability-related geomechanical and petrophysical properties. These include brittle minerals composition, fracture toughness, minimum horizontal in-situ stress, a brittleness index model, and temperature effect to quantify the rock’s fracability. The hierarchical analytic framework was designed based on the correlation between the influencing factors and rock fracability. The results of the qualitative and quantitative approaches were integrated into a mathematical evaluation model. The improved fracability index model’s reliability was evaluated using well logs and 3D seismic data on low-permeable carbonate geothermal reservoirs and shale gas horizontal wells. The results reveal that the improved FI model effectively demonstrates brittle regions in the low-permeable carbonate geothermal reservoir and long horizontal section of shale reservoir. We divide the rock fracability into three levels: FI > 0.59 (the rock fracability is good); 0.59 > FI > 0.32 (the rock fracability is medium); and FI < 0.32, (the rock fracability is poor). The improved FI model can assist in resolving the uncertainties associated with fracability interpretation in determining the optimum location of perforation clusters for hydraulic fracture initiation and propagation in enhanced geothermal systems.

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35

Gerber, Léda, and François Maréchal. "Environomic optimal configurations of geothermal energy conversion systems: Application to the future construction of Enhanced Geothermal Systems in Switzerland." Energy 45, no. 1 (September 2012): 908–23. http://dx.doi.org/10.1016/j.energy.2012.06.068.

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36

Zhou, Dejian, Alexandru Tatomir, and Martin Sauter. "Thermo-hydro-mechanical modelling study of heat extraction and flow processes in enhanced geothermal systems." Advances in Geosciences 54 (June 8, 2021): 229–40. http://dx.doi.org/10.5194/adgeo-54-229-2021.

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Abstract. Enhanced Geothermal Systems (EGS) are widely used in the development and application of geothermal energy production. They usually consist of two deep boreholes (well doublet) circulation systems, with hot water being abstracted, passed through a heat exchanger, and reinjected into the geothermal reservoir. Recently, simple analytical solutions have been proposed to estimate water pressure at the abstraction borehole. Nevertheless, these methods do not consider the influence of complex geometrical fracture patterns and the effects of the coupled thermal and mechanical processes. In this study, we implemented a coupled thermo-hydro-mechanical (THM) model to simulate the processes of heat extraction, reservoir deformation, and groundwater flow in the fractured rock reservoir. The THM model is validated with analytical solutions and existing published results. The results from the systems of single fracture zone and multi-fracture zones are investigated and compared. It shows that the growth of the number and spacing of fracture zones can effectively decrease the pore pressure difference between injection and abstraction wells; it also increases the production temperature at the abstraction, the service life-spans, and heat production rate of the geothermal reservoirs. Furthermore, the sensitivity analysis on the flow rate is also implemented. It is observed that a larger flow rate leads to a higher abstraction temperature and heat production rate at the end of the simulation, but the pressure difference may become lower.

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37

Timothy, Kneafsey. "The EGS Collab Project: An intermediate-scale field test to address enhanced geothermal system challenges." E3S Web of Conferences 205 (2020): 01002. http://dx.doi.org/10.1051/e3sconf/202020501002.

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Three components are typically needed to extract geothermal energy from the subsurface: 1. hot rock, 2. a heat transfer fluid, and 3. flow pathways contacting the fluid and the rock. These naturally occur in many locations resulting in hydrothermal systems, however there are enormous regions containing hot rock that do not naturally have adequate fluid, and/or appropriate fluid permeability to allow hot fluid extraction. Some type of engineering or enhancement of these systems would be required to extract the energy. These enormous regions provide the possibility of long-term extraction of significant quantities of energy. Enhanced (or engineered) Geothermal Systems (EGS) are engineered reservoirs created to extract economical amounts of heat from low permeability and/or porosity geothermal resources. There are technological challenges that must be addressed in order to extract the heat. These include proper stimulation, effective monitoring, reservoir control, and reservoir sustainability. The US DOE Geothermal Technologies Office and geothermal agencies from other countries have supported field tests over a range of scales and conditions. A current US field project, the EGS Collab Project, is working nearly a mile deep in crystalline rock at the Sanford Underground Research Facility (SURF) to study rock stimulation under EGS stress conditions. We are creating intermediate-scale (tens of meters) test beds via hydraulic stimulation and are circulating chilled water to model the injection of cooler water into a hot rock which would occur in an EGS, gathering high resolution data to constrain and validate thermal-hydrological-mechanical-chemical (THMC) modeling approaches. These validated approaches would then be used in the DOE’s flagship EGS field laboratory, Frontier Observatory for Research in Geothermal Energy (FORGE) underway in Milford, Utah and in commercial EGS. In the EGS Collab project, numerous stimulations have been performed, characterized, and simulated and long-term flow tests have been completed.

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38

Peacock, D. C. P., David J. Sanderson, and Bernd Leiss. "Use of Analogue Exposures of Fractured Rock for Enhanced Geothermal Systems." Geosciences 12, no. 9 (August 26, 2022): 318. http://dx.doi.org/10.3390/geosciences12090318.

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Field exposures are often used to provide useful information about sub-surface reservoirs. This paper discusses general lessons learnt about the use of deformed Devonian and Carboniferous meta-sedimentary rocks in the Harz Mountains, Germany, as analogues for a proposed enhanced geothermal reservoir (EGS) at Göttingen. The aims of any analogue study must be clarified, including agreeing with people from other disciplines (especially reservoir modellers) about the information that can and cannot be obtained from surface exposures. Choice of an analogue may not simply involve selection of the nearest exposures of rocks of a similar age and type, but should involve consideration of such factors as the quality and geological setting of the analogue and reservoir, and of any processes that need to be understood. Fieldwork should focus on solving particular problems relating to understanding the EGS, with care being needed to avoid becoming distracted by broader geological issues. It is suggested that appropriate questions should be asked and appropriate analyses used when planning a study of a geothermal reservoir, including studies of exposed analogues.

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39

Tagliaferri, Mauro, Paweł Gładysz, Pietro Ungar, Magdalena Strojny, Lorenzo Talluri, Daniele Fiaschi, Giampaolo Manfrida, Trond Andresen, and Anna Sowiżdżał. "Techno-Economic Assessment of the Supercritical Carbon Dioxide Enhanced Geothermal Systems." Sustainability 14, no. 24 (December 10, 2022): 16580. http://dx.doi.org/10.3390/su142416580.

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Enhanced geothermal systems distinguish themselves among other technologies that utilize renewable energy sources by their possibility of the partial sequestration of carbon dioxide (CO2). Thus, CO2 in its supercritical form in such units may be considered as better working fluid for heat transfer than conventionally used water. The main goal of the study was to perform the techno-economic analysis of different configurations of supercritical carbon dioxide-enhanced geothermal systems (sCO2-EGSs). The energy performance as well as economic evaluation including heat and power generation, capital and operational expenditures, and levelized cost of electricity and heat were investigated based on the results of mathematical modeling and process simulations. The results indicated that sCO2 mass flow rates and injection temperature have a significant impact on energetic results and also cost estimation. In relation to financial assessment, the highest levelized cost of electricity was obtained for the indirect sCO2 cycle (219.5 EUR/MWh) mainly due to the lower electricity production (in comparison with systems using Organic Rankine Cycle) and high investment costs. Both energy and economic assessments in this study provide a systematic approach to compare the sCO2-EGS variants.

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KC, Bijay, and Ehsan Ghazanfari. "Geothermal reservoir stimulation through hydro-shearing: an experimental study under conditions close to enhanced geothermal systems." Geothermics 96 (November 2021): 102200. http://dx.doi.org/10.1016/j.geothermics.2021.102200.

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Ledésert, Béatrice, Ronan Hébert, Ghislain Trullenque, Albert Genter, Eléonore Dalmais, and Jean Herisson. "Editorial of Special Issue “Enhanced Geothermal Systems and Other Deep Geothermal Applications throughout Europe: The MEET Project”." Geosciences 12, no. 9 (September 13, 2022): 341. http://dx.doi.org/10.3390/geosciences12090341.

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The MEET project is a Multidisciplinary and multi-context demonstration of Enhanced Geothermal Systems exploration and Exploitation Techniques and potentials, which received funding from the European Commission in the framework of the Horizon 2020 program [...]

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Buster, Grant, Paul Siratovich, Nicole Taverna, Michael Rossol, Jon Weers, Andrea Blair, Jay Huggins, et al. "A New Modeling Framework for Geothermal Operational Optimization with Machine Learning (GOOML)." Energies 14, no. 20 (October 19, 2021): 6852. http://dx.doi.org/10.3390/en14206852.

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Geothermal power plants are excellent resources for providing low carbon electricity generation with high reliability. However, many geothermal power plants could realize significant improvements in operational efficiency from the application of improved modeling software. Increased integration of digital twins into geothermal operations will not only enable engineers to better understand the complex interplay of components in larger systems but will also enable enhanced exploration of the operational space with the recent advances in artificial intelligence (AI) and machine learning (ML) tools. Such innovations in geothermal operational analysis have been deterred by several challenges, most notably, the challenge in applying idealized thermodynamic models to imperfect as-built systems with constant degradation of nominal performance. This paper presents GOOML: a new framework for Geothermal Operational Optimization with Machine Learning. By taking a hybrid data-driven thermodynamics approach, GOOML is able to accurately model the real-world performance characteristics of as-built geothermal systems. Further, GOOML can be readily integrated into the larger AI and ML ecosystem for true state-of-the-art optimization. This modeling framework has already been applied to several geothermal power plants and has provided reasonably accurate results in all cases. Therefore, we expect that the GOOML framework can be applied to any geothermal power plant around the world.

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Cui, Xin, and Louis Ngai Yuen Wong. "A 3D thermo-hydro-mechanical coupling model for enhanced geothermal systems." International Journal of Rock Mechanics and Mining Sciences 143 (July 2021): 104744. http://dx.doi.org/10.1016/j.ijrmms.2021.104744.

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Herrmann, Johannes, Valerian Schuster, Chaojie Cheng, Harald Milsch, and Erik Rybacki. "Fracture Transmissivity in Prospective Host Rocks for Enhanced Geothermal Systems (EGS)." Geosciences 12, no. 5 (May 3, 2022): 195. http://dx.doi.org/10.3390/geosciences12050195.

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We experimentally determined the hydraulic properties of fractures within various rock types, focusing on a variety of Variscan rocks. Flow-through experiments were performed on slate, graywacke, quartzite, granite, natural fault gouge, and claystone samples containing an artificial fracture with a given roughness. For slate samples, the hydraulic transmissivity of the fractures was measured at confining pressures, pc, at up to 50 MPa, temperatures, T, between 25 and 100 °C, and differential stress, 𝜎, acting perpendicular to the fracture surface of up to 45 MPa. Fracture transmissivity decreases non-linearly and irreversibly by about an order of magnitude with increasing confining pressure and differential stress, with a slightly stronger influence of pc than of 𝜎. Increasing temperature reduces fracture transmissivity only at high confining pressures when the fracture aperture is already low. An increase in the fracture surface roughness by about three times yields an initial fracture transmissivity of almost one order of magnitude higher. Fractures with similar surface roughness display the highest initial transmissivity within slate, graywacke, quartzite and granite samples, whereas the transmissivity in claystone and granitic gouge material is up to several orders of magnitude lower. The reduction in transmissivity with increasing stress at room temperature varies with composition and uniaxial strength, where the deduction is lowest for rocks with a high fraction of strong minerals and associated high brittleness and strength. Microstructural investigations suggest that the reduction is induced by the compaction of the matrix and crushing of strong asperities. Our results suggest that for a given surface roughness, the fracture transmissivity of slate as an example of a target reservoir for unconventional EGS, is comparable to that of other hard rocks, e.g., granite, whereas highly altered and/or clay-bearing rocks display poor potential for extracting geothermal energy from discrete fractures.

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Dehghani-Sanij, Alireza, and Jatin Nathwani. "Special Issue: New Trends in Enhanced, Hybrid and Integrated Geothermal Systems." Applied Sciences 11, no. 9 (April 22, 2021): 3765. http://dx.doi.org/10.3390/app11093765.

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Li, S., S. Wang, and H. Tang. "Stimulation mechanism and design of enhanced geothermal systems: A comprehensive review." Renewable and Sustainable Energy Reviews 155 (March 2022): 111914. http://dx.doi.org/10.1016/j.rser.2021.111914.

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Geng, Changyou, Xinli Lu, Hao Yu, Wei Zhang, Jiaqi Zhang, and Jiansheng Wang. "Theoretical Study of a Novel Power Cycle for Enhanced Geothermal Systems." Processes 10, no. 3 (March 4, 2022): 516. http://dx.doi.org/10.3390/pr10030516.

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As obtained geofluids from enhanced geothermal systems usually have lower temperatures and contain chemicals and impurities, a novel power cycle (NPC) with a unit capacity of several hundred kilowatts has been configured and developed in this study, with particular reference to the geofluid temperature (heat source) ranging from 110 °C to 170 °C. Using a suitable CO2-based mixture working fluid, a transcritical power cycle was developed. The novelty of the developed power cycle lies in the fact that an increasing-pressure endothermic process was realized in a few-hundred-meters-long downhole heat exchanger (DHE) by making use of gravitational potential energy, which increases the working fluid’s pressure and temperature at the turbine inlet and, hence, increases the cycle’s power output. The increasing-pressure endothermic process in the DHE has a better match with the temperature change of the heat source (geofluid), as does the exothermic process in the condenser with the temperature change of the sink (cooling water), which reduces the heat transfer irreversibility and improves the cycle efficiency. Power cycle performance has been analyzed in terms of the effects of mass fraction of the mixture working fluids, the working fluid’s flowrate and its DHE inlet pressure, geofluid flowrate, and the length of the DHE. Results show that, for a given geofluid’s temperature and mass flowrate, the cycle’s net power output is a strong function of the working-fluid’s flowrate, as well as of its DHE inlet pressure. Too high or too low of a DHE inlet pressure results in a lower power output. When geofluid temperature is 130 °C, the optimum DHE inlet pressure is found to be 11 MPa, corresponding to an optimum working-fluid flowrate of 6.5 kg/s. The longer the DHE, the greater the corresponding working-fluid flowrate and the higher the net power output. For geofluid temperature ranging from 110 °C to 170 °C, the developed NPC has a better thermodynamic performance than the conventional ORC. The advantage of using the developed NPC becomes obvious when geofluid temperature is low. The maximum net power output difference between the NPC and the ORC happens when the geofluid temperature is 130 °C and NPC’s working fluid mass fraction (R32/CO2) is 0.5/0.5.

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Limberger, J., P. Calcagno, A. Manzella, E. Trumpy, T. Boxem, M. P. D. Pluymaekers, and J. D. van Wees. "Assessing the prospective resource base for enhanced geothermal systems in Europe." Geothermal Energy Science 2, no. 1 (December 23, 2014): 55–71. http://dx.doi.org/10.5194/gtes-2-55-2014.

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<p><strong>Abstract.</strong> In this study the resource base for EGS (enhanced geothermal systems) in Europe was quantified and economically constrained, applying a discounted cash-flow model to different techno-economic scenarios for future EGS in 2020, 2030, and 2050. Temperature is a critical parameter that controls the amount of thermal energy available in the subsurface. Therefore, the first step in assessing the European resource base for EGS is the construction of a subsurface temperature model of onshore Europe. Subsurface temperatures were computed to a depth of 10 km below ground level for a regular 3-D hexahedral grid with a horizontal resolution of 10 km and a vertical resolution of 250 m. Vertical conductive heat transport was considered as the main heat transfer mechanism. Surface temperature and basal heat flow were used as boundary conditions for the top and bottom of the model, respectively. If publicly available, the most recent and comprehensive regional temperature models, based on data from wells, were incorporated. <br><br> With the modeled subsurface temperatures and future technical and economic scenarios, the technical potential and minimum levelized cost of energy (LCOE) were calculated for each grid cell of the temperature model. Calculations for a typical EGS scenario yield costs of EUR 215 MWh<sup>−1</sup> in 2020, EUR 127 MWh<sup>−1</sup> in 2030, and EUR 70 MWh<sup>−1</sup> in 2050. Cutoff values of EUR 200 MWh<sup>−1</sup> in 2020, EUR 150 MWh<sup>−1</sup> in 2030, and EUR 100 MWh<sup>−1</sup> in 2050 are imposed to the calculated LCOE values in each grid cell to limit the technical potential, resulting in an economic potential for Europe of 19 GW<sub>e</sub> in 2020, 22 GW<sub>e</sub> in 2030, and 522 GW<sub>e</sub> in 2050. The results of our approach do not only provide an indication of prospective areas for future EGS in Europe, but also show a more realistic cost determined and depth-dependent distribution of the technical potential by applying different well cost models for 2020, 2030, and 2050.</p>

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Lee, Junbeum, and Eunhyea Chung. "Application of geochemical modelling for hydraulic stimulation in enhanced geothermal systems." Geosystem Engineering 23, no. 6 (October 14, 2020): 342–50. http://dx.doi.org/10.1080/12269328.2020.1832923.

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Chandra, Divya, Caleb Conrad, Derek Hall, Nicholas Montebello, Andrew Weiner, Sarma Pisupati, Uday Turaga, Ghazal Izadi, Arun Ram Mohan, and Derek Elsworth. "Pairing Integrated Gasification and Enhanced Geothermal Systems (EGS) in Semiarid Environments." Energy & Fuels 26, no. 12 (November 8, 2012): 7378–89. http://dx.doi.org/10.1021/ef301397n.

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