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Netherlands Journal of Geosciences e12-11 Sensitivity of aquifer support Methodology Van der Meulen (2016) demonstrated that the absence of a proper aquifer obstructs synergy between hydrocarbon- and geothermal energy production due to a severe drop of reservoir pressure and con- sequently both systems interfering with one another. To mimic this behaviour, the aquifer size of the Roden reservoir model is reduced to nearly a third (Figure 15). Furthermore, another scenario is tested which assumes a very strong aquifer drive. This is achieved by intro- ducing a pressure boundary condition in the water zone on the edges of the reservoir model. In both sensitivity analyses the previously used 16 geothermal well configurations are used to test the impact of the aquifer support on the total gas production. Results Limiting the size of the aquifer decreases the total gas production, with no geothermal doublet active, to 3.69 BCM when compared with the reference model (Table A2 in the Appendix; Figure 16A). Water breakthrough starts in 1985. The addition of an active geothermal doublet shows that altering both geothermal producer and -injector distances has a limited effect. The increase of geother- mal flow rate also shows a limited increase of total gas production (Figure 16A). With the limited aquifer, the BHP decreases quite rapidly and the minimum BHP constraint of 15 bar is reached (Figure 16B). The flow rate of ROD-102 is lowered in order to maintain this minimum BHP. The presence of a strong aquifer drive also leads to a lower cumulative gas production (3.70 BCM) when compared with the reference model (Table A2 in the Appendix; Figure 17A). The effect of changing the distance of the geothermal injector is less sig- nificant than the effect of changing the geothermal producer’s dis- tance. Increasing the geothermal flow rate leads to a more or less Figure 13. Results of sensitivity analysis of well configuration and reservoir permeability trend on cumu- lative gas production of ROD-102. (A) Varying geothermal producer and -injector distances and geothermal flow rates; (B) bottom hole pressure. Figure 14. Resultsofsensitivityanaly- sis of well configuration and reservoir permeability trend inversed on cumula- tive gas production of ROD-102. (A) Varying geothermal producer and -injector distances and geothermal flow rates; (B) bottom hole pressure. linear increase of total gas production (Figure 17A). The most sig- nificant effect of the strong aquifer drive is the reduced decrease of BHP compared with the reference model and the limited aquifer (Figure 17B). Before the start of water breakthrough the BHP remains close to its initial steady-state pressure. For both scenarios, a geothermal well configuration with the geothermal production well at 250 m from the GWC, geothermal injection well 2000 m from the geothermal producer and a geother- mal flow rate of 250 Sm3 h−1 leads to the highest gas recovery increase (Table A2 in the Appendix). Sensitivity to the timing of geothermal production start Methodology With many gas fields in the Netherlands being well underway in their production life, it is interesting to see what the (theoretical) impact is of geothermal exploitation on the potential synergy in the various stages of gas production. Using the original reference model, simulations are run to test this effect given the following timings of geothermal production: 1. Simultaneous start of gas- and geothermal production; 2. Halfway before water breakthrough; 3. At start of water breakthrough; 4. When ROD-102 closes in due to excessive water production, with gas production restarting 4 years later; 5. When ROD-102 closes in due to excessive water production, with gas production restarting 10 years later. The geothermal well configuration used to test these five scenarios includes a geothermal producer at 500 m from the GWC, the geo- thermal injector at 2500 m from the GWC and a flow rate of 250 Sm3 h−1. 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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