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e12-8 Jeroen van der Molen et al. Figure 7. Results of sensitivity analysis of well configuration on cumulative gas pro- duction of ROD-102, with varying geothermal producer and -injector distances and geothermal flow rates using the reference model. in ROD-102 is also reflected in the BHP (Figure 8). Synchronously, the BHP of the geothermal producer and geothermal injector decreases at a more or less similar rate to the ROD-102 well. When ROD-102 shuts in, the BHP in the geothermal wells stabilises and remains constant (Figure 8). For both production systems, the BHP constraint is not reached. Increasing the distance of the geothermal producer with regard to the GWC leads to a decrease in total gas production (Figure 7), but an increase in BHP for the geothermal producer (Figure 8A). The opposite occurs when increasing the distance of the geother- mal injector with regard to the geothermal producer and thus the GWC: total gas production increases (Figure 7) while the BHP in the geothermal producer decreases (Figure 8B). Enlarging the geo- thermal flow rate results in a more or less linear increase of total gas production (Figure 7). Sensitivity to production rate of the ROD-102 well Methodology The flow rate of the ROD-102 gas production well is increased from 800,000 Sm3 d−1 to 1,200,000 Sm3 d−1 in order to test the effect of higher flow rates of the gas producer on the potential synergy. An alternative base case scenario is simulated to be used as a reference for the scenarios including geothermal wells. Sixteen out of the 24 geothermal well configurations described in the pre- Figure 8. Comparison of bottom hole pressures of ROD-102, geothermal producer and -injector for: (A) different geothermal producer distances, with geothermal injec- tor at 1000 m and geothermal flow rate Q = 100 Sm3 h−1; (B) different geothermal injec- tor distances, with geothermal producer at 250 m and Q = 200 Sm3 h−1; (C) different geothermal flow rates, with geothermal producer at 500 m and -injector at 1000 m. production (Figure 9A) compared with the reference model (Figure 7A). Increasing the distance of the geothermal injector and having the geothermal producer at 250m from the GWC also shows a comparable rise in total gas production to that in the reference model. However, with the geothermal producer at 500 m, increasing the distance of the geothermal injector does not show (a significant) change in total gas production (Figure 9A). With an increased gas production rate the highest gas recovery increase is shown by the synergy scenario with a 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. vious section are used. The WGR is lowered to 0.000167 Sm3 Sm−3 3 −1 in order to maintain the 200 Sm d water production limit. Results Increasing the gas flow rate to 1,200,000 Sm3 d−1 and having no geothermal exploitation leads to a lower cumulative gas production of 4.28 BCM (Table A2 in the Appendix; Figure 9A) compared to the reference model. Water breakthrough starts in 1982, ROD-102 shutdown in 1986. The addition of the geothermal system again enhances total gas production owing to a delay in water break- through (Table A2 in the Appendix; Figure 9A); the relative increase due to the geothermal system is slightly higher than in the reference model. The higher gas flow rate results in a more rapid decrease of BHP compared to the base case gas flow of 800,000 Sm3 d−1 (Figure 9B). Increasing the horizontal distance of the geothermal producer with respect to the GWC shows a similar behaviour in total gas 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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