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e12-10 Jeroen van der Molen et al. Figure 11. Map view of the main fault block of the Roden gas field with an increasing permeability trend from the ROD-102 well towards the geothermal wells. Figure 12. Results of sensitivity analy- sis of well configuration and reservoir permeability doubled on cumulative gas production of ROD-102. (A) Varying geothermal producer and -injector distances and geothermal flow rates; (B) bottom hole pressure. the geothermal injector has no effect on the total amount of gas produced (Figure 12A). This is also shown with having the geo- thermal injector at 1500 m from the geothermal producer resulting in the highest increase in gas recovery versus the geothermal injec- tor at 2000 m. A reservoir permeability that decreases away from ROD-102 shows a slight increase (4.78 BCM) in total gas production, with no geothermal doublet active, when compared to the reference model (Table A2 in the Appendix; Figure 13A). When the geother- mal system is introduced, the most significant differences in total gas production can be attributed to the flow rate of the doublet. At a flow rate of 100 m3 h−1 the change in distance of the injector has no impact; increasing the flow rate makes this change more apparent. With higher flow rates the relative increase of total gas production is reduced (Figure 13A). The BHP behaviour is not very different to that in the reference model (Figure 13B). The optimum geothermal well configuration in this scenario is having the geothermal producer at 250 m from the GWC, the geothermal injector 2000 m from the geothermal producer and a geothermal flow rate of 250 Sm3 h−1 (Table A2 in the Appendix). The reservoir permeability decreasing from the geothermal injector towards ROD-102 shows the opposite behaviour to that described above. Total production of gas, without geothermal wells, is less (4.29 BCM) than in the reference model (Table A2 in the Appendix; Figure 14A). The effect of altering the geothermal injector distance is subordinate to the effect of changing the distance of the geothermal producer with regard to the GWC. This difference becomes more pronounced with higher geothermal flow rates (Figure 14A). The BHP of ROD-102 shows that the minimum pressure constraint of 15 bar is reached in all synergy scenarios before ROD-102 is shut in due to water breakthrough (Figure 14B). A geothermal well configuration, where the geother- mal producer is at a distance of 250 m from the GWC, the geother- mal injector 1500 m from the geothermal producer and having a geothermal flow rate of 250 Sm3 h−1, results in the highest increase in gas recovery. Downloaded from https://www.cambridge.org/core. IP address: 173.229.12.141, on 13 Jan 2021 at 23:29:16, subject to the Cambridge Core terms of use, available at https://www.cambridge.org/core/terms. https://doi.org/10.1017/njg.2019.11PDF Image | Dual hydrocarbon–geothermal energy exploitation
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