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Rotliegendes
Estimating the Maximum Magnitude of Induced Earthquakes in the Groningen Gas Field, the Netherlands
Aeolian-Lacustrine margins: Implications for Carbon Capture and Storage within the Rotliegend Group, Southern North Sea
Diagenetic History and Timing of Cu and Zn-Pb Sulfide Mineralization in the Permian Kupferschiefer System, Saale Subbasin, Eastern Germany
Use of exploration methods to repurpose and extend the life of a super basin as a carbon storage hub for the energy transition
Geological evaluation of suprasalt carbon storage opportunities in the Silverpit Basin, United Kingdom Southern North Sea
Sedimentary evolution of the Pennsylvanian–Permian Mulargia–Escalaplano molassic basin (Sardinia, Italy): the most complete record in the Southern Variscan Realm
The role of the underburden at Elgin Franklin in the understanding of the overburden 4D signal
Deep learning for end-to-end subsurface modeling and interpretation: An example from the Groningen gas field
Grylloblattidan insects from Sperbersbach and Cabarz (Germany), two new early Permian and insect-rich localities
A FIB-SEM Study of Illite Morphology in Aeolian Rotliegend Sandstones: Implications for Understanding the Petrophysical Properties of Reservoir Rocks
Estimating subsurface properties using a semisupervised neural network approach
Origin, migration pathways, and prediction of high carbon dioxide accumulations in the Lower Saxony Basin (northwestern Germany): Part II
The Kilmar Field, Block 43/22a, UK North Sea
Abstract The Kilmar Field, part of the Tors complex (Kilmar and Garrow fields), was discovered in 1992 and is located on the northern margins of the Southern North Sea Basin. Gas is produced from Namurian sandstones, at a depth of 11 000 ft, from a 25 km 2 closure at the Base Permian level. The reservoir was deposited as a series of stacked channel sandstones in a fluvio-deltaic setting. Seismic imaging of intra-Carboniferous strata is limited, so mapping of individual bodies of sandstone is not achievable. The development philosophy has been to maximize the drilled lengths of specific reservoir units and to contact multiple sandstone bodies by drilling long, high-angle, multi-bore production wells. The sandstones are of low to medium porosity and permeability, supplemented by connection through a fracture network. At project sanction in 2005, the combined gas-in-place resource in Kilmar was estimated to be 311 bcf and a total of 75 bcf gas recovery from three wells was forecast. Cumulative gas production to date is 69 bcf. Whilst the gas-in-place has changed little, the distribution has changed between segments. The recovery factor for the field is 24%. Infill drilling opportunities have been identified but are gas price dependent.
Fault seal behaviour in Permian Rotliegend reservoir sequences: case studies from the Dutch Southern North Sea
Abstract Permian Rotliegend reservoir rocks are generally characterized by high net/gross (N/G) ratios, and faults in such sand-dominated lithologies are typically not considered likely to seal. Nevertheless, many examples of membrane sealing are present in Rotliegend gas fields in the Southern Permian Basin. This manuscript reviews examples of membrane sealing in the Dutch Rotliegend; it presents an extensive dataset of petrophysical properties of Rotliegend fault rocks and analyses two case studies using commonly used workflows. Fault (membrane) seal studies have been carried out on two Rotliegend fields to test the level of confidence and uncertainty of prediction of ‘across fault pressure differences’ (AFPD) based on existing SGR-based algorithms. From the field studies it is concluded that observable small AFPDs are present and that these are likely pre-production AFPDs due to exploration-time scale trapping and retention of hydrocarbons. Two shale gouge ratio (SGR)-based empirical algorithms have been used here to estimate AFPDs in lower N/G reservoir intervals with the aim of predicting membrane seal behaviour, and these results are compared to field data. It is concluded the selected SGR-based tools predict AFPD for Upper Rotliegend lower N/G reservoir rocks with reasonable results. Nonetheless, the core sample datasets show a much wider range of permeability and capillary entry pressure than predicted by the selected SGR transforms. This highlights the potential to modify existing workflows for application to faults in high N/G lithologies. Data sharing and collaboration between industry and academics is encouraged, so that in the long run workflows can be developed specifically for faults in high N/G lithologies.