The impact of late Cenozoic uplift and erosion on hydrocarbon exploration: offshore Norway and some other uplifted basins

Doré, A. G.; Jensen, L. N.

doi:10.1016/0921-8181(95)00031-3

Cited by 145 publications

(87 citation statements)

References 7 publications

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“…Following Early Eocene crustal separation, the Mid-Norway margin was partly inverted during the Late Eocene-Early Oligocene, from the Oligocene onward resulting in the nearshore areas being uplifted and deeply truncated (Holtedahl, 1953;Doré & Jensen, 1996;Clausen et al, 2000;Cloetingh et al, 2005). In Scandinavia, as in the Paleocene and the main sediment provenance were to the north and northeast during the Oligocene in contrast to the Eocene when the sediment was principally derived from the west (Clausen et al, 2000).…”

Section: Oligocenementioning

confidence: 99%

Filling the North Sea Basin: Cenozoic sediment sources and river styles

Gibbard¹,

Lewin²

2016

Geol. Belg.

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ABSTRACT. The history of the infilling of the North Sea is outlined, with particular focus on sediment sources and river inputs. In simple terms (for the detail is complex), these sources changed from domination by northwesterly sources from the Shetland area (Paleocene to Eocene), to a geographically more uniform basin-centred pattern, and then northerly input following Fennoscandian uplift (Oligocene and Neogene). Baltic inputs followed via an 'Eridanos (Baltic) River' (Miocene), with cold-climate coarser sediment inputs, and lacustrine episodes resulting from ice damming (Pleistocene). River styles in each of these phases are discussed, with the Cenozoic at first being dominated by low energy fluvial deposition (channel sands, chemically weathered clays, and organic sedimentation) in fluctuating climates. Cold climates in the latest Neogene and Quaternary are seen as major determinant of a change in fluvial style, though these are also associated with tectonic effects, as in Scandinavia. The mediating role of vegetation, relating also to temperature and precipitation, is also likely to have been significant. Narrow valley incision followed the Middle Pleistocene Transition, as well as an increasing importance of Rhine-Meuse sources that had begun earlier.

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Section: Oligocenementioning

confidence: 99%

Filling the North Sea Basin: Cenozoic sediment sources and river styles

Gibbard¹,

Lewin²

2016

Geol. Belg.

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“…Subsequently, the gas along with light hydrocarbon compounds may escape through leakage and/or remigrate (fillspill) to shallower traps in the updip direction, where lower PT conditions cause exsolution of lighter molecules. In the Barents Sea, uplift and erosion are responsible for the remigration and loss of petroleum accumulations from the traps (Doré and Jensen, 1996;Lerch, 2016;Lerch et al, 2016a, b;Nyland et al, 1992). This has resulted in oil being displaced into peripheral traps, which have partly leaking cap rocks that allow gas to escape while retaining oil (cf.…”

Section: Migrational or Evaporative Fractionation Remigration Uplifmentioning

confidence: 99%

Thermal maturity, hydrocarbon potential and kerogen type of some Triassic–Lower Cretaceous sediments from the SW Barents Sea and Svalbard

Abay

Karlsen

Pedersen

et al. 2017

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Rock-Eval and total organic carbon (TOC) analyses of 144 samples representing Triassic–Lower Cretaceous intervals from the SW Barents Sea (the Svalis Dome, the Nordkapp and Hammerfest basins, and the Bjarmeland Platform) and Svalbard demonstrate lateral variations in source rock properties. Good to excellent source rocks are present in the Lower–Middle Triassic Botneheia and Steinkobbe, and Upper Jurassic Hekkingen formations, 1 – 7 wt% and 6 – 19 wt% TOC, respectively. Hydrogen indices of 298 – 609 mg HC/g TOC in the Botneheia Formation from Svalbard, and 197 – 540 mg HC/g TOC in the Steinkobbe Formation of Svalis Dome suggest Type II (oil-prone) and Type II/III (oil/gas-prone) kerogens, respectively. The Kobbe Formation (Botneheia/Steinkobbe-equivalent) is organic-lean and generally gas-prone (Type III kerogen) on the Bjarmeland Platform and in the Nordkapp Basin, and is a good source rock with Type III/II kerogen in the Hammerfest Basin. In the investigated wells, the Hekkingen Formation is more oil-prone on the Bjarmeland Platform than in the Nordkapp Basin, while Lower Cretaceous samples have poor potential for oil. Upper Triassic samples show potential mainly for gas; however, coal/coaly-shale samples in well 7430/07-U-01 (Bjarmeland Platform) are oil/gas-prone. Most samples analysed are immature to early mature; thus, the variation in petroleum potential and kerogen type is a function of organic facies rather than maturity levels.

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“…Fluid-flow or migration is associated with excess pore-fluid pressure which can be attributed to temporal and spatially varying processes, such as rapid sediment loading (Dugan and Flemings, 2000), uplift and erosion (Doré and Jensen, 1996), dissociation of gas hydrate (Mienert et al, 2005), polygonal faulting (Andresen and Huuse, 2011;Cartwright et al, 2007;Gay et al, 2011;Ostanin et al, 2012a), and leakage from deep and shallow source and reservoir rocks (Heggland, 1998;Hovland and Judd, 1988;Solheim and Elverhøi, 1985). Focused fluid-flow systems usually serve as conduits for fluids and sediment remobilization.…”

Section: Rationalementioning

confidence: 99%

“…Increase in sedimentation rate formed huge, regional depocentres near the shelf edge offshore Mid-Norway and in front of bathymetric troughs in the northern North Sea and western Barents Sea (Faleide et al, 2008). Uplift and glacial erosion during Pliocene to Pleistocene (Dimakis et al, 1998;Doré and Jensen, 1996;Dörr et al, 2012;Faleide et al, 1996;Green and Duddy, 2010;Henriksen et al, 2011;Vorren et al, 1991) has evolved the deep marine fans in the adjacent oceanic domains along the northern and western passive margins (Knies et al, 2009). …”

Section: Tectonic Evolution Of the Southwestern Barents Seamentioning

confidence: 99%

Deep-seated faults and hydrocarbon leakage in the Snøhvit Gas Field, Hammerfest Basin, Southwestern Barents Sea

Mohammedyasin

Lippard

Omosanya

et al. 2016

Marine and Petroleum Geology

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High-quality 3D seismic data are used to analyze the history of fault growth and hydrocarbon leakage in the Snøhvit Field, southwestern Barents Sea. The aim of this work is to evaluate the role of tectonic fracturing as a mechanism driving fluid-flow in the study area. To achieve this aim, an integrated approach including seismic interpretation, multiple seismic attribute analysis, fault modeling and displacement analysis was used.The six major faults in the study area are dip-slip normal faults which are characterized by complex lateral and vertical segmentation. The three main episodes of fault reactivation interpreted were in late Jurassic (Kimmeridgian), early Cretaceous and Paleocene times. Fault reactivation in the study area is mainly through dip-linkage. Throw-distance plots of the representative faults also revealed along-strike linkage and multi-skewed C-type profiles. The throw profiles show that faults in the study area evolved through polycyclic activity involving both blind propagation, syn-sedimentary activity and that they have their maximum displacement at the reservoir zone. The expansion and growth indices provide evidence for coeval fault activity with sedimentation and interaction of the faults with a free surface during their evolution.

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The impact of late Cenozoic uplift and erosion on hydrocarbon exploration: offshore Norway and some other uplifted basins

Cited by 145 publications

References 7 publications

Filling the North Sea Basin: Cenozoic sediment sources and river styles

Filling the North Sea Basin: Cenozoic sediment sources and river styles

Thermal maturity, hydrocarbon potential and kerogen type of some Triassic–Lower Cretaceous sediments from the SW Barents Sea and Svalbard

Deep-seated faults and hydrocarbon leakage in the Snøhvit Gas Field, Hammerfest Basin, Southwestern Barents Sea

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