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Netherlands Journal of Geosciences www.cambridge.org/njg Original Article Cite this article: van der Molen J, Peters E, Jedari-Eyvazi F, and van Gessel SF. Dual hydrocarbon–geothermal energy exploitation: potential synergy between the production of natural gas and warm water from the subsurface. Netherlands Journal of Geosciences, Volume 98, e12. https://doi.org/10.1017/ njg.2019.11 Received: 24 May 2019 Revised: 5 November 2019 Accepted: 11 November 2019 Keywords: geothermal; energy; synergy; hydrocarbon; dual; exploitation Author for correspondence: Jeroen van der Molen, Email: Jeroen.vandermolen@tno.nl Dual hydrocarbon–geothermal energy exploitation: potential synergy between the production of natural gas and warm water from the subsurface Jeroen van der Molen1 , Elisabeth Peters1, Farid Jedari-Eyvazi2 and Serge F. van Gessel1 1TNO, Princetonlaan 6, 3584 CB, Utrecht, the Netherlands and 2GESciTech, 33 Wood Street, Barnet, Hertfordshire EN5 4BE, UK Abstract The decline of domestic natural gas production, increasing dependency on gas imports and lagging development of renewable energy production may pose serious challenges to the current high standards of secure energy supply in the Netherlands. This paper examines synergy between hydrocarbon- and geothermal exploitation as a means to reinforce energy security. The Roden gas field is used as an example to demonstrate potential delay of water breakthrough in the gas well and a resulting increase of recovered gas (up to 19%), by positioning of a geo- thermal doublet in the water leg of the gas field. The reservoir simulations show that the total increase of gas production primarily depends on the amount of aquifer support. An optimal configuration of gas- and geothermal wells is key to maximise gas recovery and strongly depends on the distribution of reservoir properties. The study also reveals that this option can still be beneficial for gas fields in a late stage of production. Net Present Value calculations show that the added value from the geothermal doublet on total gas production could lead to an early repayment of initial investments in the geothermal project, thereby reducing the overall financial risk. If no subsidies are taken into account, the additional profits can also be used to finance the geothermal project up to break-even level within 15 years. However, this comes with a cost as the additional profits from improved gas recovery are significantly reduced. © The Author(s) 2020. This is an Open Access article, distributed under the terms of the Creative Commons Attribution licence (http:// creativecommons.org/licenses/by/4.0/), which permits unrestricted re-use, distribution, and reproduction in any medium, provided the original work is properly cited. Introduction The energy system in the Netherlands is subject to substantial changes. The Dutch Energieagenda (MEA, 2016) targets a 95% reduction of greenhouse gas emissions, compared to the 1990 emissions levels, by 2050. In this respect, the replacement of fossil fuels (coal, gas, oil) by clean and renewable sources (wind, solar, biomass and geothermal) represents one of the key pillars of climate and energy policies. However, as domestic production of natural gas steadily declines, the fossil-to-renewable transition becomes more urgent. The high invest- ment costs associated with a rapid transition, the disappearing backbone of secure fossil energy production and the measures to balance the high shares of intermittent renewables may form a challenging hurdle to this transition. Synergies between natural gas production and develop- ment of renewable production may help to mitigate these issues. The Netherlands has proven to be one of the largest natural gas producers in the European Union (Juez-Larré et al., 2016; Honoré, 2017). Over the past 70 years both the on- and offshore territories have been thoroughly explored and produced (Breunese et al., 2005; Geluk & De Jager, 2012). Natural gas production in the Netherlands has steadily declined since 2014, however, as most fields enter tail-end production while the rate of new discoveries being added to the portfolio is decreasing (MEA, 2018). The impacts of induced earthquakes related to gas production from the Groningen gas field (Van Geuns & Van Thienen-Visser 2017) have led to the decision by the Dutch government to lower the annual production from the Groningen gas field to 12 billion cubic metres (BCM) per annum and to fully halt production by 2030 (Wiebes, 2018). However, a later statement by the Dutch government declares that production from the Groningen gas field could be (close to) 0 from 2022 onwards (Wiebes, 2019). Furthermore, the coalition agreement of the Dutch government states that onshore no new exploration licen- ces for hydrocarbons will be awarded (Rutte et al., 2017). Consequently, the Netherlands is shifting from being a leading natural gas exporter in western Europe to being a net importer of natural gas (Van Geuns et al. 2017), while simultaneously trying to phase out natural gas as an energy source. As the development of renewables in the Netherlands is lagging, the demand for natural gas in the Netherlands remains significant, with more than 50% of electricity 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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