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Netherlands
Facies prediction with Bayesian inference: Application of supervised and semisupervised deep learning
Machine-learning assisted interpretation: Integrated fault prediction and extraction case study from the Groningen gas field, Netherlands
Origin of shallow gas in the Dutch North Sea — Seismic versus geochemical evidence
Seismic depositional sequence characterization by using enhanced multichannel variational-mode decomposition
Estimating subsurface properties using a semisupervised neural network approach
Full‐Wavefield, Full‐Domain Deterministic Modeling of Shallow Low‐Magnitude Events for Improving Regional Ground‐Motion Predictions
FMHex20: An earthquake focal mechanism database for seismotectonic analyses in metropolitan France and bordering regions
Uncertainty quantification in fault detection using convolutional neural networks
Near-surface diffractor detection at archaeological sites based on an interferometric workflow
Automatic seismic facies interpretation using supervised deep learning
Drill core from seismically active sandstone gas reservoir yields clues to internal deformation mechanisms
Harvesting geothermal energy with low unit cost installations
On the electromagnetic response of complex pipeline infrastructure
Geothermal potential of the Tubbergen Formation in the Twente region of east Netherlands
UKCS exploration: 50 years and counting
Abstract Exploration drilling activity, discovery history and creaming curves in the offshore UK are analysed for each UK Continental Shelf (UKCS) basin and each play in the North Sea from the earliest wells drilled in 1965 until the end of 2017. Around 52 Bboe of commercially recoverable oil and gas has been discovered, with around half of this volume found in the first 10 years of exploration. UKCS exploration plays are generally at a mature or super-mature stage and the exploration challenges reflect this. Although technical success rates have steadily increased since the 1990s, pool sizes are becoming smaller. In the last 10 years the average commercial discovery size has been 27 MMboe recoverable, and since 2010 only 10% of discoveries have been bigger than 43 MMboe recoverable. The UK Oil and Gas Authority's 6 Bboe mid-case yet-to-find estimate, as published in 2018, would take 40 years to unlock at the current rate of discovery. Future exploration in the mature UKCS is intertwined with prolonging the life of production infrastructure and is increasingly dependent on the development of new low-cost development concepts. Increased focus on the search for subtle traps, and more reliable pre-drill risk and volume estimation through improved benchmarking and calibration will be key to future exploration success.
Tracking 3D seismic horizons with a new hybrid tracking algorithm
Probabilistic Moment Tensor Inversion for Hydrocarbon‐Induced Seismicity in the Groningen Gas Field, The Netherlands, Part 1: Testing
Probabilistic Moment Tensor Inversion for Hydrocarbon‐Induced Seismicity in the Groningen Gas Field, the Netherlands, Part 2: Application
Ground‐Motion Attenuation, Stress Drop, and Directivity of Induced Events in the Groningen Gas Field by Spectral Inversion of Borehole Records
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.