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Geology of Humber Group : Central Graben and Moray Firth, UKCS (1996)

Geological Society (London, U.K.) ; Hurst, Andrew ; Johnson, Howard D. ; [et al.]

London : The Geological Society

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Keywords: Malm ; Zentrale Nordsee ; Geology ; Hydrocarbons ; North Sea

Description / Table of Contents: J. J. Veldkamp, M. G. Gaillard, H. A. Jonkers, B. K. Levell, M. G. Gaillard, and H. A. Jonkers: A Kimmeridgian time-slice through the Humber Group of the central North Sea: a test of sequence stratigraphic methods / Geological Society, London, Special Publications, 114:1-28, doi:10.1144/GSL.SP.1996.114.01.01 --- Alan Carruthers, Tom Mckie, John Price, Robin Dyer, Gwydion Williams, and Paul Watson: The application of sequence stratigraphy to the understanding of Late Jurassic turbidite plays in the Central North Sea, UKCS / Geological Society, London, Special Publications, 114:29-45, doi:10.1144/GSL.SP.1996.114.01.02 --- M. J. David: History of hydrocarbon exploration in the Moray Firth / Geological Society, London, Special Publications, 114:47-80, doi:10.1144/GSL.SP.1996.114.01.03 --- Richard J. Davies, Kevin J. Stephen, John R. Underhill, Richard J. Davies, and Kevin J. Stephen: A re-evaluation of Middle and Upper Jurassic stratigraphy and the flooding history of the Moray Firth Rift System, North Sea / Geological Society, London, Special Publications, 114:81-108, doi:10.1144/GSL.SP.1996.114.01.04 --- S. D. Harker and M. Rieuf: Genetic stratigraphy and sandstone distribution of the Moray Firth Humber Group (Upper Jurassic) / Geological Society, London, Special Publications, 114:109-130, doi:10.1144/GSL.SP.1996.114.01.05 --- Claire R. Hallsworth, Andrew C. Morton, and Graham Dore: Contrasting mineralogy of Upper Jurassic sandstones in the Outer Moray Firth, North Sea: implications for the evolution of sediment dispersal patterns / Geological Society, London, Special Publications, 114:131-144, doi:10.1144/GSL.SP.1996.114.01.06 --- R. E. Frost and J. F. Rose: Tectonic quiescence punctuated by strike-slip movement: influences on Late Jurassic sedimentation in the Moray Firth and the North Sea region / Geological Society, London, Special Publications, 114:145-162, doi:10.1144/GSL.SP.1996.114.01.07 --- M. A. Martin, J. E. Pollard, and M. A. Martin: The role of trace fossil (ichnofabric) analysis in the development of depositional models for the Upper Jurassic Fulmar Formation of the Kittiwake Field (Quadrant 21 UKCS) / Geological Society, London, Special Publications, 114:163-183, doi:10.1144/GSL.SP.1996.114.01.08 --- Stuart Gowland: Facies characteristics and depositional models of highly bioturbated shallow marine siliciclastic strata: an example from the Fulmar Formation (Late Jurassic), UK Central Graben / Geological Society, London, Special Publications, 114:185-214, doi:10.1144/GSL.SP.1996.114.01.09 --- S. J. C. Cannon and S. Gowland: Facies controls on reservoir quality in the Late Jurassic Fulmar Formation, Quadrant 21, UKCS / Geological Society, London, Special Publications, 114:215-233, doi:10.1144/GSL.SP.1996.114.01.10 --- Geoff Freer, Andrew Hurst, and Paul Middleton: Upper Jurassic sandstone reservoir quality and distribution on the Fladen Ground Spur / Geological Society, London, Special Publications, 114:235-249, doi:10.1144/GSL.SP.1996.114.01.11 --- C. Y. McCants and S. D. Burley: Reservoir architecture and diagenesis in downthrown fault block plays: the Lowlander Prospect of Block 14/20b, Witch Ground Graben, Outer Moray Firth, UK North Sea / Geological Society, London, Special Publications, 114:251-285, doi:10.1144/GSL.SP.1996.114.01.12 --- Michael J. Pearson, Alasdair D. Duncan, and Alasdair D. Duncan: Biomarker maturity profiles in the Inner Moray Firth Basin and implications for inversion estimates / Geological Society, London, Special Publications, 114:287-298, doi:10.1144/GSL.SP.1996.114.01.13 --- B. Dickinson: The Puffin Field: the appraisal of a complex HP-HT gas-condensate accumulation / Geological Society, London, Special Publications, 114:299-327, doi:10.1144/GSL.SP.1996.114.01.14 --- Susan Currie: The development of the Ivanhoe, Rob Roy and Hamish Fields, Block 15/21A, UK North Sea / Geological Society, London, Special Publications, 114:329-341, doi:10.1144/GSL.SP.1996.114.01.15

Pages: Online-Ressource (350 Seiten) , Illustrationen, Diagramme, Karten

ISBN: 1897799705

URL: http://sp.lyellcollection.org/content/114/1

Language: English

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Thin section and S.E.M. textural criteria for the recognition of cement-dissolution porosity in sandstones (1986)

BURLEY, S. D. ; KANTOROWICZ, J. D.

Oxford, UK : Blackwell Publishing Ltd

Sedimentology 33 (1986), S. 0

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ISSN: 1365-3091

Source: Blackwell Publishing Journal Backfiles 1879-2005

Topics: Geosciences

Notes: Cement-porosity relationships are described from the Lower Triassic Sherwood Sandstone Group and the Middle Jurassic Ravenscar Group in the United Kingdom. Calcite cemented sandstones display a variety of replacement textures, with preferential replacement of grains and of overgrowth faces with high free-surface energy. Dolomite and siderite cemented sandstones display similar textures but replacement is less specific and euhedral overgrowth surfaces are commonly embayed by carbonates. Examination of the more porous sandstones with the scanning electron microscope reveals a range of pitting and embayment textures in authigenic overgrowths and in detrital grains. These range from small ‘v’-shaped notches and pits, through regular and irregular shaped embayments, into large depressions. These textures appear to be morphologically similar to the quartz surfaces seen in thin sections of carbonate cemented sandstones, and are interpreted to have been formed by the dissolution of pore-filling and grain replacive authigenic carbonates. This is confirmed by examination of experimentally exhumed overgrowth surfaces from carbonate cemented sandstones. These textures indicate that part of the intergranular porosity in these sediments is secondary in origin, and has been generated by the dissolution of carbonate cements. The identification of such textures may lead to a more confident interpretation of the nature of intergranular porosity in the subsurface.

Type of Medium: Electronic Resource

URL: http://dx.doi.org/10.1111/j.1365-3091.1986.tb00763.x

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REPLY (1986)

BURLEY, S. D. ; KANTOROWICZ, J. D.

Oxford, UK : Blackwell Publishing Ltd

Sedimentology 33 (1986), S. 0

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ISSN: 1365-3091

Source: Blackwell Publishing Journal Backfiles 1879-2005

Topics: Geosciences

Type of Medium: Electronic Resource

URL: http://dx.doi.org/10.1111/j.1365-3091.1986.tb00765.x

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Integrated four-dimensional modelling of sedimentary basin architecture and hydrocarbon migration (2007)

Clarke, S. M. ; Burley, S. D. ; Williams, G. D. ; [et al.]

In: Geological Society Special Publication 253: 185-211.

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Publication Date: 2007-10-08

Description: Structural geometries, faults and their movement histories, together with the petrophysical properties of flow units, are some of the major controls on hydrocarbon migration pathways within sedimentary basins. Currently, structural restoration, fault-seal analysis and hydrocarbon migration are treated as separate approaches to investigating basin geohistory and petroleum systems. Each of these separate modelling approaches in their own fields is advanced and sophisticated but they are not compatible with each other. Lack of integration produces incorrect palaeogeometries in basin models and inaccurate migration pathways. A combined structural restoration and fault-seal analysis technique, integrated with fast hydrocarbon migration pathway modelling code based on invasion percolation (IP) methods, is described. These modelling methods are used to develop a 4D basin modelling workflow in which evolving basin geohistories and geometries form an integral part of the analysis of hydrocarbon migration and trapping. By combining structural restoration and 3D fault-seal analysis it is possible to investigate the evolution of structurally complex traps through time. Integration of these techniques with a numerically fast migration pathway modelling technique allows hydrocarbon migration pathways and accumulations to be modelled through the evolution of the basin with time. Additionally, the effects of uncertainties in structural geometry, fault seal or any of the model input parameters can be explored using a risk-driven approach to modelling. These methods are demonstrated using synthetic, computer generated, 3D models and a well-constrained model of the Moab Fault, Utah, USA. Comparison of modelled structural geometries, fault-seal properties and predicted trapped hydrocarbons with outcrop data is used to validate the integrated modelling approach. The validated techniques are then applied to a seismically derived, 3D model from the southern North Sea, UK, to demonstrate how an integrated, risk-driven approach to modelling allows the effects of uncertainties in the distribution of hydrocarbon accumulations to be investigated.

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Geochemical characterization of oils and their source rocks in the Barmer Basin, Rajasthan, India (2015)

Farrimond, P., Naidu, B. S., Burley, S. D., Dolson, J., Whiteley, N., Kothari, V.

Geological Society of London

In: Petroleum Geoscience

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Publication Date: 2015-10-17

Description: The Barmer Basin is a failed continental rift of late Cretaceous–Eocene age in Rajasthan, NW India, containing prolific hydrocarbon resources, with 33 discoveries having been made in the last decade. The basin is predominantly oil-prone, although gas discoveries have been made in the deeper parts of the basin. Oils in the Barmer Basin are highly waxy, a result of the lacustrine nature of the source rocks that dominate the sedimentary fill of the basin. Detailed interpretation of the molecular composition of the oils defines three main oil groups that can be related to differing sources. The oils are all distinctively lacustrine in origin, although differing in specific source-facies characteristics. All of the oils are isotopically light, mostly in the –29 to –33 range. Most oils in the northern Barmer Basin (groups 1A and 1B) are interpreted to have been generated from the Late Paleocene Barmer Hill Formation, an excellent oil-prone source rock with predominantly Type I lacustrine algal and bacterial kerogen. Group 2 oils are subordinate in abundance, occurring only in the southern part of the basin, and are interpreted to be at least partly sourced from the overlying Early Eocene Dharvi Dungar Formation, which is characterized by mixed Type I and Type III kerogen, and attains oil maturity only in the southern basin. Group 3 oils are less common, and are of higher maturity than the Group 1 oils, but also appear to have been generated from the Barmer Hill Formation where it was buried more deeply in the central and southern parts of the basin. However, recognition of probable Mesozoic sediments in sub-basins beneath the Tertiary Barmer Basin introduces a further source-rock candidate for the Group 3 oils. A high maturity hydrocarbon charge that is recognized in the gasoline-range hydrocarbons in the Group 2 oils of the southern Barmer Basin may also be from a Mesozoic source rock, or from the Barmer Hill Formation that is much more deeply buried in this part of the basin than in the north, and represents a more mixed oil- and gas-prone source.

Print ISSN: 1354-0793

Topics: Chemistry and Pharmacology , Geosciences

Published by Geological Society of London

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The discovery of the Barmer Basin, Rajasthan, India, and its petroleum geology (2015)

Dolson, J., Burley, S. D., Sunder, V. R., Kothari, V., Naidu, B., Whiteley, N. P., Farrimond, P., Taylor, A., Direen, N., Ananthakrishnan, B.

American Association of Petroleum Geologists (AAPG)

In: AAPG Bulletin

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Publication Date: 2015-03-03

Description: The discovery of oil and gas in the Barmer Basin in northwest India was one of the more significant global discoveries in the decade 2001–2010. The basin’s presence was suspected from gravity and magnetic data in the late 1980s but not confirmed until 1999 from seismic and drilling. The basin is a lacustrine failed rift. Biostratigraphic data, however, indicate it was intermittently connected to marine waters via either the Cambay Basin, the Kutch Basin, or across the Devikot high, temporarily forming a large, shallow estuary. At least six major tectono-stratigraphic events have caused relative lake level falls and translation of clastic reservoirs basinward. Upward of 6 km (~20,000 ft) of Cenozoic and Mesozoic sedimentary rocks have been preserved. Prolific source rocks occur from the Mesozoic through Eocene strata. Tectonically, the basin is divided into a northern and a southern province. The north province continues to undergo inversion and erosion, and has not been buried as deeply as the south. Kinetics of the major source facies in the north are substantially different from those in the south, as well as the present-day and paleo-heat flow. These differences have made the northern part of the basin predominantly an oil province and the southern part a mixed oil and gas province. The prolific Paleocene Fatehgarh Formation contains the bulk of the 7.3 billion barrels of stock tank oil in place (STOIP) identified to date, but other reservoirs from the Mesozoic to the late Cenozoic are common and may yield significant future resource additions.

Print ISSN: 0149-1423

Electronic ISSN: 0149-1423

Topics: Geosciences