A dynamic deterministic model of hydrocarbon generation in the Midgard Field drainage area offshore Mid-Norway

Mo, E. S.; Throndsen, Torbjørn; Andresen, Peter L.; Bäckstrøm, Sven A.; Forsberg, A.; Haug, S.; Tørudbakken, B. O.

doi:10.1007/bf01988366

Cited by 12 publications

(4 citation statements)

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“…Obaje and Hamza (2000) and Obaje et al (2004) discussed the generation of petroleum from Cretaceous coals in the Middle Benue Trough and the Gongola Basin (Upper Benue Trough), onshore Nigeria. Elvsborg et al (1985) and Mo et al (1989) regarded the coals in the Lower Jurassic Åre Formation as an important source for oil and condensate in the Midgard field, offshore Mid-Norway. Cohen and Dunn (1987) and Karlsen et al (1995) considered shales of the Upper Jurassic Spekk Formation to be of greater importance as source rocks, although they suggested that oil generated by the Åre Formation may have contributed to the build-up of and at the Trym discovery, Norwegian North Sea (Petersen and Brekke, 2001).…”

Section: Oil From Coalsmentioning

confidence: 99%

Oil‐prone Lower Carboniferous Coals in the Norwegian Barents Sea: Implications for a Palaeozoic Petroleum System

Koeverden

Karlsen

Schwark

et al. 2010

Journal of Petroleum Geology

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In this study, we assess the oil generation potential of Lower Carboniferous, liptinite-rich coals in the Tettegras Formation on the Finnmark Platform, southern Norwegian Barents Sea. Oil from these coals has been expelled into intercalated sandstones. The coals may have contributed to petroleum recorded in well 7128/4-1 on the Finnmark Platform and may constitute a new Palaeozoic source rock in the Barents Sea.The Tettegras Formation coals contain up to 80 vol. % liptinite (mineral matter free base) and have low oxygen indices. Hydrogen indices up to 367 mg HC/g TOC indicate liquid hydrocarbon potential. In wells 7128/4-1 and 7128/6-1, the coals have vitrinite reflectance R o = 0.75-0.85 %. Compared to shale and carbonate source rocks, expulsion from coal in general begins at higher maturities (R o = 0.8-0.9% and T max = 444-453°C). Thus, the coals in the wells are mostly immature with regard to oil expulsion. The oil in well 7128/4-1 most likely originates from a more mature part of the Tettegras Formation in the deeper northern part of the Finnmark Platform. Wide variations in biomarker facies parameters and δ 13 C isotope values indicate a heterogeneous paralic depositional setting. The preferential retention by coal strata of naphthenes (e.g. terpanes and steranes) and aromatic compounds, compared to n-alkanes and acyclic isoprenoids, results in a terrigenous and waxy oil. This oil however contains marine biomarkers derived from the intercalated shales and siltstones. It is therefore important to consider the entire coal-bearing sequence, including the intercalated shales, in terms of source rock potential.Coals of similar age occur on Svalbard and Bjørnøya. The results of this study therefore suggest that a Lower Carboniferous coaly source rock may extend over large areas of the Norwegian Barents Sea. This source rock is mature in areas where the otherwise prolific Upper Jurassic marine shales are either immature or missing and may constitute a new Palaeozoic coal-sourced petroleum system in the Barents Sea.

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Section: Oil From Coalsmentioning

confidence: 99%

Oil‐prone Lower Carboniferous Coals in the Norwegian Barents Sea: Implications for a Palaeozoic Petroleum System

Koeverden

Karlsen

Schwark

et al. 2010

Journal of Petroleum Geology

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“…(i) Its petroleum system includes well-studied source and reservoir rocks (Karlsen et al, 1995; and references therein). Following the initial Midgard gas-condensate discovery in 1981, the region was perceived to be gas-prone because the Middle Jurassic Åre Formation coals were erroneously proposed to be the major source rocks based on modelling studies and geochemistry (Elvsborg et al, 1985;Mo et al, 1989). However, from 1983 to 1987, a series of oil and gas/condensate accumulations were discovered in this region, including the undersaturated oils in the Draugen and Heidrun fields, and geochemical studies showed that marine shales could be important source rocks (Cohen and Dunn, 1987;Karlsen et al, 1995).…”

Section: Introductionmentioning

confidence: 99%

Petroleum Migration, Faults and Overpressure, Part I: Calibrating Basin Modelling Using Petroleum in Traps - A Review

Karlsen¹,

Skeie²

2006

J Petroleum Geol

104

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the existence of oil or gas in both present-day and palaeo-accumulations of petroleum.Trapped petroleum represents an excellent source of information about hydrocarbon generation, expulsion, migration and accumulation, and the analysis of reservoired petroleum is a key tool in hydrocarbon exploration. Most geological information relates to the static rock framework, but oil which has moved through rock strata contains within it unique information for example on carrier interconnectivity and migration directions. Migrated petroleum also provides information on both source rock facies and temperatures of maturation and expulsion. In addition, physical changes which affected the petroleum during the migration process are preserved as geochemical "fingerprints"; these changes can be interpreted in terms of the mixing of different petroleums in a trap, leakage from the trap, biodegradation and mode of migration. Most processes affecting petroleum during migration and in a trap, whether they are biochemical, physical or This paper considers the principles of deciphering basin-scale hydrocarbon migration patterns using the geochemical information which is present in trapped petroleum. Petroleum accumulations in subsiding basins can be thought of as "data archives" within which stored information can help us to understand aspects of hydrocarbon formation and migration. This information can impart a time-resolved picture of hydrocarbon migration in a basin in response to processes associated with progressive burial, particularly in the context of the occurrence and periodic activity of faults.This review, which includes a series of tentative models of migration-related processes in the extensional Halten Terrace area, offshore mid-Norway, illustrates how we can use information from the migrating mobile hydrocarbon phase to improve our knowledge of the static geological system. Of particular importance is the role of sub-seismic heterogeneities and faults in controlling migration processes. We focus on how the secondary migration process can be enhanced in a multi-source rock basin such as the Halten Terrace, thereby increasing prospectivity.

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“…In order to match present day observed temperatures (DST and Horner corrected log temperatures), however a Quaternary heatflow increase in event 35 and 36 is necessary. The necessity of a Quaternary heatflow increase has been previously observed by numerous authors (e.g., Mo et al, 1989;Dahl and Yu¨kler, 1991;Dahl and Augustson, 1993), and its significance and probable causes have been discussed in great detail by Jensen and Dore´(1993). It is important to point out that this pulse is not an actual lithospheric phenomenon, but an artefact caused by the inadequacy of modelling software to handle complex geological situations, such as rapid burial, overpressuring and fluid flow (Jensen and Dore´, 1993).…”

Section: D Model Optimisation and Heatflow Historymentioning

confidence: 87%

Geothermal history and petroleum generation in the Norwegian South Viking Graben revealed by pseudo-3D basin modelling

Justwan

Meisingset²,

Dahl

et al. 2006

Marine and Petroleum Geology

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A dynamic deterministic model of hydrocarbon generation in the Midgard Field drainage area offshore Mid-Norway

Cited by 12 publications

References 11 publications

Oil‐prone Lower Carboniferous Coals in the Norwegian Barents Sea: Implications for a Palaeozoic Petroleum System

Oil‐prone Lower Carboniferous Coals in the Norwegian Barents Sea: Implications for a Palaeozoic Petroleum System

Petroleum Migration, Faults and Overpressure, Part I: Calibrating Basin Modelling Using Petroleum in Traps - A Review

Geothermal history and petroleum generation in the Norwegian South Viking Graben revealed by pseudo-3D basin modelling

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