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. 2023 Jan 23;14:362. doi: 10.1038/s41467-023-36034-w

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© The Author(s) 2023

Open Access This article is licensed under a Creative Commons Attribution 4.0 International License, which permits use, sharing, adaptation, distribution and reproduction in any medium or format, as long as you give appropriate credit to the original author(s) and the source, provide a link to the Creative Commons license, and indicate if changes were made. The images or other third party material in this article are included in the article’s Creative Commons license, unless indicated otherwise in a credit line to the material. If material is not included in the article’s Creative Commons license and your intended use is not permitted by statutory regulation or exceeds the permitted use, you will need to obtain permission directly from the copyright holder. To view a copy of this license, visit http://creativecommons.org/licenses/by/4.0/.

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Fig. 5 — Fracture network of the numerical geothermal reservoir with 116 fractures. The aperture (a) is calculated based on an assumed stress field oriented roughly north to south. Line thickness is enhanced for visibility. Injection (red) and production borehole (blue) are marked for two well configurations: 1 (asterisks) and 2 (diamonds). The flow rate is maximum along preferential flow paths within the network (b). Aperture varies with fracture orientation within the stress field (c). Distribution of resulting heat transfer coefficients (d).