Late Palaeozoic hydrocarbon migration through the Clair field, West of Shetland, UK Atlantic margin

Mark, Darren F.; Green, Paul F.; Parnell, John; Kelley, Simon P.; Lee, Martin; Sherlock, Sarah C.

doi:10.1016/j.gca.2007.11.037

Cited by 24 publications

(12 citation statements)

References 81 publications

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“…The dating of oil charge by this method also has the potential to indicate sources of oil otherwise unrecognized, by providing a date inconsistent with the generation of oil from previously assumed sources. This was demonstrated by Ar–Ar dating of K‐feldspar cements in the Clair Field, West of Shetland (Mark et al . 2008).…”

Section: Palaeofluid Analysismentioning

confidence: 77%

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Potential of palaeofluid analysis for understanding oil charge history

Parnell¹

2010

Geofluids

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Fluid inclusion data, particularly the distribution of hydrocarbon fluid inclusions and their chemistry, can provide insights into oil charge in a petroleum-prospective region. Examples from the UK Atlantic margin show how we can understand thermal regime, timing and chemistry of oil charge. Data from the UK Atlantic margin based on fluid inclusion temperature profiles shows anomalously high temperatures which are highest at the top of the Triassic-Eocene sequence. This is interpreted as a product of hot fluid flow, probably reflecting hydrothermal activity related to intrusion of sills at depth. The preservation of high temperatures also implies rapid migration from depth through fracture systems. Ar-Ar analysis of oil-bearing K-feldspar cements, and petrographic studies of oil inclusion distribution help delimit timing and migration pathways for the hot fluid charge and later fluid migration events. Coupled with compositional data for oils measured destructively (organic geochemistry) or non-destructively (fluorescence), these approaches allow the development of oil charge histories based on real data rather than theoretical modelling.

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Section: Palaeofluid Analysismentioning

confidence: 77%

“…2005). Where oil inclusions occur in the cements, a date for oil occurrence within the sandstone is obtained, which constrains the timing of oil charge (Mark et al . 2005, 2008).…”

Section: Palaeofluid Analysismentioning

confidence: 99%

Potential of palaeofluid analysis for understanding oil charge history

Parnell¹

2010

Geofluids

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“…The Miocene and younger structures in the northern part of the Faroe -Shetland Basin are therefore more difficult to explain in this way, although there are some indications of a higher-temperature regime at that time in the results of apatite fission track and vitrinite reflectance studies (e.g. Mark et al 2008). Where a particularly strong thermal anomaly occurred, conditions could lie outside the range indicated in Figure 5, although a qualitative assessment of the impact can be made on the basis of extrapolation of the trends seen in that figure.…”

Section: Discussionmentioning

confidence: 99%

Controls on the location of compressional deformation on the NW European margin

Kimbell

Stewart

Gradmann

et al. 2016

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The distribution of Cenozoic compressional structures along the NW European margin has been compared with maps of the thickness of the crystalline crust derived from a compilation of seismic refraction interpretations and gravity modelling, and with the distribution of high-velocity lower crust and/or partially serpentinized upper mantle detected by seismic experiments. Only a subset of the mapped compressional structures coincide with areas susceptible to lithospheric weakening as a result of crustal hyperextension and partial serpentinization of the upper mantle. Notably, partially serpentinized upper mantle is well documented beneath the central part of the southern Rockall Basin, but compressional features are sparse in that area. Where compressional structures have formed but the upper mantle is not serpentinized, simple rheological modelling suggests an alternative weakening mechanism involving ductile lower crust and lithospheric decoupling. The presence of pre-existing weak zones (associated with the properties of the gouge and overpressure in fault zones) and local stress magnitude and orientation are important contributing factors.Gold Open Access: This article is published under the terms of the CC-BY 3.0 license.

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“…Comprehensive understanding of the history and intensity of oil charge is a key to successive petroleum exploration [1,2] . Fluid inclusion analysis is one of the main approaches commonly used in field-filling history investigations [48][49][50][51][52][53] . Fluid inclusions are small samples (usually <10 μm in diameter) of reservoir fluid sealed off from the formation during the crystallization of framework minerals such as quart, feldspar, and carbonates.…”

Section: Timing and Intensity Of Oil Chargementioning

confidence: 99%

Overpressure development and oil charging in the central Junggar Basin, Northwest China: Implication for petroleum exploration

Cai¹

2009

Sci. China Ser. D-Earth Sci.

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The Junggar Basin is one of the largest and most petroliferous superimposed petroleum basins in China. The central depression area has become the frontier field for petroleum exploration. The characteristics of potential source rocks and reservoir sandstones, and the pressure regime in the central Junggar Basin were studied. Permian shales are dominated by hydrogen-rich, oil-prone algal organic matter, and Jurassic mudstones are dominated by hydrogen-poor, higher-plant derived organic matter. These source rocks are widespread and have been mature for hydrocarbon generation, suggesting good to excellent exploration potential, both for crude oils and for natural gases. The deeply buried Jurassic sandstones usually have low porosity and permeability. However, sandstones beneath the Jurassic/Cretaceous unconformity display relatively high porosity and permeability, suggesting that meteoric water leaching had improved the quality of the sandstones. Overpressure developed over much of the central Junggar Basin. The overpressured rocks are characterized by slightly increased interval transit time, low sandstone permeability, increased organic matter maturity, and high relative hydrocarbon-gas contents. Mudstones in the overpressured system have quite the same clay mineral compositions as mudstones in the lower part of the normally pressured system. Overpressure generation in the central Junggar Basin is best to be explained as the result of hydrocarbon generation and fluid retention in low-permeability rocks. Petroleum generated from Permian and Jurassic source rocks could migrate laterally through preferential petroleum migration pathways and accumulated in structural traps or lithological traps in the overpressured system, or migrate vertically through faults/ hydraulic fractures into the overlying, normally pressured system and accumulate in structural or lithological traps. Therefore, commercial petroleum reservoirs could be potentially found in both the overpressured system, and in the normally pressured system. pressure regime, overpressure generation, oil charge, petroleum exploration potential, Junggar BasinAs petroleum exploration and development in Cenozoic lacustrine basins increases, finding oil and gas reserves in superimposed basins has become an important strategy in China [1,2] . Superimposed basins refer to sedimentary basins that resulted either from the contemporaneous composition of different proto-type basins or from the superimposition of proto-type basins of different stages [3] . The Junggar Basin, which began to develop in Carboniferous, is one of the largest and most petroliferous superimposed sedimentary basins in China. So far over 20 major oil fields have been found in the basin. These fields had produced a total oil output of over 2×10 8 t by the end of 2005 [4] .Up to the present, most commercial oil and gas fields were found in basin margins or on the uplifts in the Junggar Basin. As petroleum exploration in basin margins and uplift areas goes into the mature phase, finding

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Late Palaeozoic hydrocarbon migration through the Clair field, West of Shetland, UK Atlantic margin

Cited by 24 publications

References 81 publications

Potential of palaeofluid analysis for understanding oil charge history

Potential of palaeofluid analysis for understanding oil charge history

Controls on the location of compressional deformation on the NW European margin

Overpressure development and oil charging in the central Junggar Basin, Northwest China: Implication for petroleum exploration

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