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Netherlands Journal of Geosciences e12-5 Figure 4. Main fault block of the Roden gas field reservoir model. Grey zone represents the shaly sand interval, while the yellow zone represents the sand interval. the Petrel E&P Software Platform 2017.2 (Figure 4). Dynamic modelling has been carried out using the Eclipse 100 (2018.1) Reservoir Simulator. As the main purpose of the simulations is to gain insight into the sensitivities of various production and reservoir parameters that have an impact on the potential synergy, no history match has been made with historical production data and only the ROD-102 well has been used. Tested sensitivities are: 1. Horizontal distance (250, 500 and 750 m) of the geothermal producer with regard to the gas–water contact (GWC); 2. Horizontal distance (1000, 1500 and 2000 m) of the geothermal injector with regard to the geothermal producer; 3. Flow rates (100, 150, 200 and 250 standard cubic metres per hour (Sm3 h−1)) of the geothermal doublet; 4. Flow rates (800,000 and 1,200,000 Sm3 d−1) of the gas producer ROD-102; 5. Permeability (homogeneous, doubled homogeneous, trend and inversed trend); 6. Aquifer support (limited aquifer and strong aquifer); 7. Timing of the start of geothermal exploitation. In all scenarios the reference model of the Roden field has been used for comparison, unless noted otherwise. For each alternative development scenario a separate base case, referring to the gas production only, is defined. This base case is used as a reference for the specific scenario it belongs to. Simulations are set to start at 1 January 1977 and run for 40 years until 1 January 2017. In all sensitivity scenarios apart from no. 7, geothermal and gas production start simultaneously. For every scenario two graphs are presented: (a) cumulative gas production vs geothermal flow rate and (b) bottom hole pressure (BHP) vs year. Within the first graph the resulting cumulative gas production with respect to the imposed geothermal flow rate (100, 150, 200 and 250 Sm3 h−1) for (minimal) four geothermal well configurations is shown. Note that the resulting cumulative gas production of the scenario-specific base case (only gas production) is shown at a geothermal flow rate of 0 Sm3 h−1. In the second graph the BHP is plotted against the year of production. Here the base case of the reference model is given, with the base case of the specific scenario and the most extreme (low and high) results. Results of all other simulations are plotted between these low and high extreme outcomes. The total amount of gas produced and a comparison with base case values of every simulated scenario are given in the Appendix. As many scenarios are presented in this paper, the methodology and the results are combined to improve readability. For each (alternative) scenario the set-up is explained, followed by its results and their sensitivity to the parameter settings. The reference model Methodology The reservoir model outlines the main fault block of the Roden gas field and the connected aquifer. It comprises two reservoir inter- vals: an upper shaly sand interval, based on the ROCLT and shaly upper part of the ROSL, and a lower sand interval, based on the lower part of the ROSL. Reservoir properties of both intervals were determined from a petrophysical evaluation of the ROD-101(-S2), ROD-102 and ROD-201-S1 wells and are summarised in Table 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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