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Netherlands Journal of Geosciences e12-3 in the gas cap and thus delays the timing of water breakthrough at the gas production well. Consequently the production lifetime of the gas well is extended and the ultimate gas recovery is increased (Peters et al., 2014; Van der Meulen, unpublished MSc thesis, 2016). This paper presents and discusses the results of an in-depth sensitivity analysis based on this concept, using a reservoir model of the Roden gas field as a test case. The Roden gas field The Roden gas field is located in the northeastern part of the Netherlands, west of the Groningen gas field (Figure 2). The well ROD-01 (nowadays called ROD-101) discovered the field in 1970. The field consists of two fault blocks with major bounding faults delineating the northern, western and southern field margins, and a gentle eastward slope on the eastern side (Figure 3). In 1976, the well ROD-102 was drilled targeting the centre of the crest in the main fault block. Subsequently, the well ROD-201 (and sidetrack) was drilled targeting the southern block. Following this drill sequence, the field was brought onstream. ROD-201 already ceased production in 1984 due to a high water cut. In 1988, ROD- 101 also suffered severe water production, but was sidetracked updip (ROD-101-S2). The remaining wells produced until 2002, when ROD-102 ceased natural gas production following liquid loading. The year after, ROD-101-S2 also stopped producing; all wells are currently (ready to be) abandoned. In total, 6.5 BCM has been produced, resulting in a recovery factor of nearly 70% (NAM, 2003). In its production life, the reservoir pressure has dropped from 345 to roughly 100 bar. However, ten years after Figure 2. Map of Groningen area and its gas fields, high- lighting location of the Roden and Groningen gas fields. cessation of production, reservoir pressure has increased back to 187 bar (Godderij et al. 2018). While the initial decrease in pressure suggests a depletion drive, the relatively early breakthrough of water and the recovery of reservoir pressure after production ceased also suggests the presence of a moderate aquifer drive. The reservoir of the Roden gas field comprises the Permian Upper Rotliegend Group. Initial production of natural gas occurred from the Slochteren Sandstone Formation (ROSL). This formation consists mainly of a sequence of good porous and permeable sand- stones and conglomerates with minor intercalations of claystone (Van Adrichem Boogaert & Kouwe, 1997). In the study area the ROSL is of fluvial origin (Geluk, 2007). Based on the well log data, the thickness of the ROSL is between 140 and 220 m. The upper 20 to 30 m of the ROSL in the Roden gas field is more shaly in nature. The Ten Boer Member (ROCLT) of the Silverpit Formation conformably overlies the ROSL. This interval of mostly sandy clay- and siltstones also contains numerous sandstone stringers. The ROCLT was deposited in a lacustrine (playa) setting (Geluk, 2007). Thickness of ROCLT in the Roden gas field ranges between 20 and 30 m. In later stages of production, the ROCLT was perfo- rated and produced. The Upper Rotliegend Group is covered by the strata of the Zechstein Group, of which especially the thick sequen- ces of rock salt act as a regional seal (Geluk, 2007). Methodology and results In order to test the potential synergy between hydrocarbon- and geothermal energy production at the Roden gas field, a static res- ervoir model of the main segment of this gas field was created using 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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