Early Tertiary sinistral transpression and fault reactivation in the western Vøring Basin, Norwegian Sea: Implications for hydrocarbon exploration and pre-breakup deformation in ocean margin basins

AAPG Bulletin ◽  
2005 ◽  
Vol 89 (8) ◽  
pp. 1043-1069 ◽  
Author(s):  
J. Imber ◽  
R. E. Holdsworth ◽  
K. J. W. McCaffrey ◽  
R. W. Wilson ◽  
R. R. Jones ◽  
...  
Keyword(s):  
Fault Reactivation ◽  
Hydrocarbon Exploration ◽  
Norwegian Sea ◽  
Early Tertiary ◽  
Vøring Basin

Origin of carbonate-cemented beds on the Naglfar Dome, Vøring Basin, Norwegian Sea

2001 ◽  
Vol 18 (2) ◽  
pp. 223-234 ◽  
Author(s):  
M.B.E Mørk ◽  
D.A Leith ◽  
S Fanavoll
Keyword(s):  
Norwegian Sea ◽  
Vøring Basin

scholarly journals Hybrid event beds dominated by transitional-flow facies: character, distribution and significance in the Maastrichtian Springar Formation, north-west Vøring Basin, Norwegian Sea

Sedimentology ◽  
2017 ◽  
Vol 64 (3) ◽  
pp. 747-776 ◽  
Author(s):  
Sarah J. Southern ◽  
Ian A. Kane ◽  
Michał J. Warchoł ◽  
Kristin W. Porten ◽  
William D. McCaffrey
Keyword(s):  
Transitional Flow ◽  
Norwegian Sea ◽  
North West ◽  
Character Distribution ◽  
Vøring Basin ◽  
Hybrid Event

Mineralogical control on mudstone compaction: a study of Late Cretaceous to Early Tertiary mudstones of the Vøring and Møre basins, Norwegian Sea

2008 ◽  
Vol 14 (2) ◽  
pp. 127-138 ◽  
Author(s):  
Christer Peltonen ◽  
Øyvind Marcussen ◽  
Knut Bjørlykke ◽  
Jens Jahren
Keyword(s):  
Late Cretaceous ◽  
Norwegian Sea ◽  
Early Tertiary

New exploration discoveries in a mature basin: offshore Denmark

2016 ◽  
Vol 8 (1) ◽  
pp. 287-306 ◽  
Author(s):  
Graham Goffey ◽  
Mark Attree ◽  
Paul Curtis ◽  
Fiona Goodfellow ◽  
Jeremy Lynch ◽  
...  
Keyword(s):  
Pore Pressure ◽  
Fault Reactivation ◽  
Hydrocarbon Exploration ◽  
Salt Diapir ◽  
Gas Reservoir ◽  
John 1 ◽  
Incised Valley ◽  
Seal Integrity ◽  
Seal Failure ◽  
Induced Stress

AbstractIn 2011, two discoveries were drilled by PA Resources in the Danish sector. The Broder Tuck 2/2A wells were drilled on a thrusted anticlinal structure, downdip of the apparently small U-1X gas discovery. The wells found an excellent quality gas reservoir within an interpreted Callovian lowstand incised valley containing braided fluvial and marginal-marine sandstones. A top and base seal are provided by mudstones of the over- and underlying transgressive systems tracts respectively. The development of a base seal is key to the presence of a potentially commercial resource downdip of a relatively unpromising old well.The Lille John 1/1B wells were then drilled on a salt diapir on which 1980s wells had encountered shallow oil shows. Lille John 1 found slightly biodegraded 34° API oil in Miocene sandstones at the uncommonly shallow depth of −910 m true vertical depth subsea (TVDSS). The reservoir is full to spill, whilst the trap developed intermittently through latest Miocene–Late Pleistocene times. It is interpreted that a deeper Chalk accumulation temporarily lost seal integrity owing to glacially induced stress or overpressure triggering top-seal failure or fault reactivation during and after latest Pleistocene diapir inflation. The wider hydrocarbon exploration implications of glaciation on stress, pore pressure and trap integrity appear to be underappreciated.

Characterization and origin of large Campanian depressions within the Chalk Group of the Danish Central Graben – implications for hydrocarbon exploration and development

2020 ◽  
pp. SP509-2019-126
Author(s):  
Florian W. H. Smit ◽  
Lars Stemmerik ◽  
Mikael Lüthje ◽  
Frans S. P. van Buchem
Keyword(s):  
Lower Cretaceous ◽  
Current System ◽  
Isotope Analysis ◽  
Fault Reactivation ◽  
Hydrocarbon Exploration ◽  
Source Rocks ◽  
Bottom Current ◽  
Current Activity ◽  
Fluid Venting ◽  
Gas Bearing

AbstractThis study re-examines large and deep U-shaped reflections (2–4 km wide and 100–200 m deep) within the Upper Cretaceous–Danian Chalk Group in the inverted Roar Basin of the Danish North Sea, previously interpreted as a moat associated with a contour-parallel current system and/or erosive channels formed by gravity-driven turbidites. Improved 3D seismic data quality and seismic interpretation techniques helped to identify overlooked reflection terminations, which suggest that rather than a linear depression, the U-shaped reflections outline several bowl-shaped depressions. In addition, vertical high-amplitude columns and vertical discontinuity zones within and below the depressions were recognized and interpreted to indicate the presence of small fluid pipes, suggesting that the formation of the depressions is more complex. Carbon isotope analysis of high acoustic impedance beds within the underlying Lower Cretaceous chalk showed negative δ13C values down to −20‰, and are interpreted to indicate sediments influenced by methane-derived authigenic carbonates. Permo-Triassic half-grabens seem to have been a major source of gas-bearing fluids, as evidenced by hydrocarbon leakage phenomena within Triassic–Lower Cretaceous strata. In areas where Zechstein salt is present, the leakage root lies at salt welds, causing the formation of focused seismic reflection wipe-out and dim zones. In areas where salt was absent, the leakage root comprises a much more diffuse zone across the fault boundaries of the Permo-Triassic half-graben, and gas chimneys are characterized seismically as broad vertical dim zones up to 10 km wide. Campanian inversion tectonics caused fault reactivation and several hundreds of metres of uplift in the Roar Basin, which created an instability for the trapped gas-bearing fluids. Gentle fluid venting through observed pipes caused sediment suspension and entrainment, which could be carried away by bottom-current activity, causing localized zones of non-deposition and the formation of individual depressions. This model thus does not disregard the role of bottom-current activity in the formation of the depressions, yet it includes a fluid-venting element that fits better with the architecture and overall evidence for fluid-venting features in pre-chalk strata, as well as in the Chalk Group. Importantly, it shows that prior to the thermogenic maturation of the main source rock (i.e. the Bo Member of the Farsund Formation in the Late Miocene), fluid venting had already occurred on the Late Cretaceous seafloor from deeper source rocks that are at present overmature.

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