Abstract
Abstract Reservoir quality assessment was conducted from petrophysical analysis and rock physics diagnostics on 15 wells penetrating Middle Jurassic sandstone reservoir formations in different regions of the eastern Central North Sea. Seismic interpretation on available 3D and 2D seismic reflection data was utilized to map thickness variations and to draw broad correlations to structural features such as salt structures and faults. In the central Egersund Basin, the Sandnes Formation shows good reservoir properties (gross thickness = 107–147 m, N/G = 33–53%) while the Bryne Formation exhibits poorer reservoir quality (N/G
Highlights
There are clearly issues related to overall source rock maturation, but successful wells in certain areas prove local oil generation
We focus on reservoir quality variations, thickness differences and potential target formations in areas where hydrocarbon generation and migration can plausibly occur
A clear change in the velocity (Vs) gradient with increasing density is shown to occur in data from eight exploration wells
Summary
The UK Kimmeridge Clay Formation equivalents, i.e., Draupne, Tau, and Hekkingen formations (popularly referred to as hot shales or black [paper] shales) are prolific source rocks for oil and gas and are excellent candidates for studying the effects of changing organic content, composition and maturation (Pedersen et al, 2006) These formations are a result of rising sea level and marine transgression from Bathonian to Kimmeridgian times, coupled with the restricted seafloor environments created by the pronounced Late Jurassic rift topography (Fig. 6; Larsen, 1987; Torsvik et al, 2002; Faleide et al, 2015; Fazlikhani et al, 2017). Late Cretaceous sediments vary from thick, characteristic Shetland Group carbonate sequences in the North Sea, to siliciclastic (shallow) marine deposits in the Barents Sea that are typically condensed as a result of uplift, erosion, and/or nondeposition (Torsvik et al, 2002; Faleide et al, 2015)
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