Chapter 17 Uplift and erosion of the greater Barents Sea: impact on prospectivity and petroleum systems

Henriksen, E.; Bjørnseth, H.M.; Hals, T.K.; Heide, T. van der; Kiryukhina, T. A.; Kløvjan, O.S.; Larssen, Geir Birger; Ryseth, Alf; Rønning, K.; Sollid, K.; Stoupakova, A.V.

doi:10.1144/m35.17

Cited by 173 publications

(229 citation statements)

References 32 publications

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“…Cornford, 1998;Tissot and Welte, 1984). An example of remigration of oil related to uplift events is the case of the Barents Sea region, resulting in dry wells with palaeo-oil saturation (Henriksen et al, 2011;Nyland et al, 1992;Ohm et al, 2008). Issues of remigration are the subject of Paper 5.…”

Section: Seal Rocks and Trapsmentioning

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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Section: Seal Rocks and Trapsmentioning

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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“…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%

“…Growth index records can indicate the timing and depict the growth history of faults (Henriksen et al, 2011;Hongxing and Anderson, 2007;Pochat et al, 2009). It is a measure of relative throw rate to the sedimentation rate in the footwall.…”

Section: = Thickness Of Hangingwall Stratamentioning

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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“…8b). Given that the study area is localized in the western part of the HB, we attribute this difference to a decreasing trend of net erosion amount towards the western margin of the Barents Sea as described by Henriksen et al (2011a).…”

Section: Discussionmentioning

confidence: 99%

“…Henriksen et al (2011a) provide a literature review of the erosion amount estimates and driving forces of the Cenozoic uplift. They suggest the following possible uplift and erosion mechanisms: (a) Opening of the Atlantic and Arctic Oceans, (b) compression and/or transpression, (c) isostatic response to sediment unloading and (d) postglacial rebound.…”

Section: Discussionmentioning

confidence: 99%

Assessment of the Cenozoic Erosion Amount Using Monte Carlo Type-Petroleum Systems Modeling of the Hammerfest Basin, Western Barents Sea

Zięba¹,

Daszinnies²,

Emmel³

et al. 2014

American Journal of Geoscience

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The Cenozoic uplift and erosion is often believed to be a major risk factor in hydrocarbon exploration in the Barents Sea causing petroleum redistribution and leakage from filled traps. Therefore, the estimation of erosion amount is an important but often underrepresented task in the basin modeling procedure. The assessment of erosion magnitudes and spatial distribution by geochemical and thermo chronological methods results in very different estimates and/or does not consider uncertainties of input data. In this study, this problem is approached by using Monte Carlo simulation techniques in secondary migration basin modeling. Thereby, amounts of early and late Cenozoic erosion episodes are described by probability distributions and the modeling results were evaluated considering their uncertainty ranges. In addition, overpressure and related leakage scenarios are considered in the petroleum basin models to study their effect on modeling results. It is shown that the early Cenozoic erosion event had a generally higher erosion magnitude than the late Cenozoic event (1.0-1.3 and 0.4-1.2 km respectively). Modeled erosion estimates are not very sensitive to overpressure modeling which is found to affect only the early Cenozoic erosion amount estimates at low degree.

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Chapter 17 Uplift and erosion of the greater Barents Sea: impact on prospectivity and petroleum systems

Cited by 173 publications

References 32 publications

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

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

Assessment of the Cenozoic Erosion Amount Using Monte Carlo Type-Petroleum Systems Modeling of the Hammerfest Basin, Western Barents Sea

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