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« GARAH

Geological Analysis and Resource Assessment of selected Hydrocarbon systems

Base layers

Layers

0 Petroleum Systems in the North Sea

Hydrocarbon fields

Hydrocarbon fields in the North Sea. This dataset contains information about the types of hydrocarbon, status, start year and operator. The dataset is compiled by the GARAH project and is based on data from the National Data Repositories from Norway, Denmark, Germany, The Netherlands and The UK.

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0 Unconventional gas plays

Bo member

Bo member. Colours are based on the estimate of free gas in 10⁹ m3 for the percentile P50

More information is found in the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin

100 m Kimmeridge Clay and equivalents

100 m Kimmeridge Clay equivalent. Colours are based on the estimate of free gas in 10⁹ m3 for the percentile P50. A 100 m thick slice of kimmeridge clay and its equvalents is assumed to be more realistic with respect to development and exploitation than the whole unit thickness.

More information is found in the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin

Kimmeridge Clay and equivalents

The Kimmeridge Clay and the Mandal Formation. Ages from the Upper Jurassic to Lower Cretaceous. Colours are based on the estimate of free gas in 10⁹ m3 for the percentile P50

More information is found in the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin

Posidonia and equivalents

The Posidonia shale from the Lower Jurassic. Colours are based on the estimate of free gas in 10⁹ m3 for the percentile P50.

More information is found in the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin

Sleen Formation

The Sleen Formation from the Upper Triassic (Rhaetian) in the German Central Graben. Colours are based on the estimate of free gas in 10⁹ m3 for the percentile P50.

More information is found in the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin . A description of the attributes is also found in the metadata description.

Bowland and equivalents

The Bowland Hodder shale and the Geverik Member from the Carboniferous. Colours are based on the estimate of free gas in 10⁹ m3 for the percentile P50

More information is found in the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin

0 Unconventional oil plays

Bo Member and equivalents

Bo Member and the Hot Shale from the Lower Cretaceous. Colours are based on the estimate of free oil in 10⁶ m3 for the percentile P50.

More information is found in the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin .

100 m Kimmeridge Clay and equivalents

100 m thickness of the Kimmeridge Clay and the Mandal Formation. Ages from the Upper Jurassic to Lower Cretaceous. A 100 m thick slice of kimmeridge clay and its equvalents is assumed to be more realistic with respect to development and exploitation than the whole unit thickness. Colours are based on the estimate of free oil in 10⁶ m3 for the percentile P50.

More information is found in the metadata description and the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin .

Kimmeridge Clay and equivalents

The Kimmeridge Clay and the Mandal Formation. Ages from the Upper Jurassic to Lower Cretaceous. Colours are based on the estimate of free oil in 10⁶ m3 for the percentile P50.

More information is found in the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin and in the metadata description.

Posidonia and equivalents

Posidonia shale and equivalents from the Lower Jurassic. Colours are based on the estimate of free oil in 10⁶ m3 for the percentile P50.

More information is found in the metadata description and the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin .

Sleen Formation

The Sleen Formation from the Upper Triassic (Rhaetian) in the German Central Graben. Colours are based on the estimate of free oil in 10⁶ m3 for the percentile P50.

More information is found in the metadata description and the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin .

0 Conventional Plays

Shallow Gas

Shallow Gas.

A detailed description about lithology, structures, ages etc is given in the attribute table. Further information is found in the report Deliverable 2.3. Updated assessment of the conventional and unconventional resources of the North Sea Basin .

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Eocene

Eocene.

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Lower Eocene

Lower Eocene.

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Paleocene

Paleocene.

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Upper Cretaceous

Upper Cretaceous.

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Lower Cretaceous

Lower Cretaceous.

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Upper Jurassic

Upper Jurassic.

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Middle Jurassic

Middle Jurassic.

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Lower Jurassic

Lower Jurassic.

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Triassic

Triassic.

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Zechstein

Zechstein.

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Permian Rotliegend

Permian Rotliegend.

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Carboniferous

Carboniferous.

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Devonian

Devonian.

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0 3D study unconventional resources

Profile line

Cross section through the 3D model. Links to profiles that show stratigraphy and content of generated petroleum

GIIP

Modelled amounts of gas for different source rocks. BEWARE that some of the polygons are overlapping/identical

OIIP

Modelled amounts of oil for different source rocks. BEWARE that some of the polygons are overlapping/identical

Vitrinite reflectance at the Base Cretaceous Unconformity subcrop.

Calculated vitrinite reflectance (EASY%Ro) at the Base Cretaceous Unconformity subcrop. The subcrop covers the Top Upper Jurassic, Top Lower Jurassic and Triassic

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Average vitrinite reflectance for the Upper Jurassic

Calculated average vitrinite reflectance (EASY%Ro) for the Upper Jurassic interval

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Average transformation ratio for the Upper Jurassic

Calculated average transformation ratio (TR all) for the Upper Jurassic interval. The transformation ratio (TR) as defined by Tissot and Welte (1984) is the ratio of the petroleum (oil and gas) actually formed by the kerogen to the total amount of petroleum that the kerogen is capable of generating.

Average vitrinite reflectance for the Lower Jurassic

Calculated average vitrinite reflectance (EASY%Ro) for the Lower Jurassic interval.

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Vitrinite reflectance at the Top Lower Jurassic

Calculated vitrinite reflectance (EASY%Ro) at the Top Lower Jurassic

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Average transformation ratio for the Lower Jurassic

Calculated average transformation ratio (TR all) for the Lower Jurassic interval. The transformation ratio (TR) as defined by Tissot and Welte (1984) is the ratio of the petroleum (oil and gas) actually formed by the kerogen to the total amount of petroleum that the kerogen is capable of generating.

Wells used for calibration

Wells used for calibration of the model

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Study area

3D Study area

The results of the studies are described in

Deliverable 2.4. 3D Pilot Study - Unconventionals

Deliverable 2.5. 3D Pilot Study - Conventionals

0 3D study conventional resources

Profile line

Cross section through the 3D model with link to profile that shows hydrocarbon migration and accumulations. For further explanation see figure 14 in the report Deliverable 2.5. 3D Pilot Study - Conventionals

Source rocks

The extent of the four source rocks in the 3D model study area

From figure 11 in 3D Pilot Study - Conventionals

Source rock:

Modelled accumulation of hydrocarbons

Example showing the distribution of accumulations after introducing more reservoir layers and tighter shaly lithologies in the overburden to force pressure built-up in the upper part of the Cenozoic section. The areas marked by coloured circles represent areas where majority of HCs are accumulated in the individual reservoir layer shown in the upper right corner. Remaining accumulations not encircled are areas where HCs accumulate in Upper Cretaceous reservoir.

From figure 18 in in the report Deliverable 2.5. 3D Pilot Study - Conventionals

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Study area

3D Study area

0 Structural elements

Salt Structures

Salt diapirs and salt pillows in the North Sea Area. The source of data is described in the attribute table.

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Basins and highs (from NAG-TEC)

Basins and highs from NAG-TEC: Northeast Atlantic Geoscience Tectonostratigraphic Atlas

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Ages of structural elements (from NAG-TEC)

Basins and highs from NAG-TEC: Northeast Atlantic Geoscience Tectonostratigraphic Atlas . The symbolization is based on the age of the structual element

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Regions of structural elements (from NAG-TEC)

Structural regions from NAG-TEC: Northeast Atlantic Geoscience Tectonostratigraphic Atlas .

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0 Alternative use

CO2 Storage

Assessment of CO2 Storage Potential in Europe

Final Report
Executive Summary

WMS

Area of interest

Area of interest of the GARAH project workpackage 2. The GARAH project focuses on the petroleum systems of both conventional and unconventional resources in the North Sea.

0 Gas hydrates

0 Accessment

Susceptibility

Likelihood of occurrence (below seafloor) of marine hydrates in the sediment column, and subsequently the likelihood of them being affected by dissociation processes resulting from natural or human-induced activities (liquefaction, explosions, collapse, crater-like depressions or submarine landslides).

Reference: https://doi.org/10.3390/app11062865

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Susceptibility Reliability

Reliability of the susceptibility assessment to the presence of marine hydrate deposits. It based on the density of geographical data taken into account in the susceptibility assessment.

Reference: https://doi.org/10.3390/app11062865

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0 Knowledge Gap

Knowledge gap assessment of hydrate evidence and indicators

Density map of hydrate evidence (samples of hydrates in gravity cores or wells) and indicators (seismic anomalies or geochemical indicators). It has been developed with the "point density" algorithm of ArcGIS®. Pixel value, number of data per 100,000 km2. Parameters: population field, none; cell size, 5000; radius, 178,415 metres; areal units, square kilometres; method, geodesic. Knowledge gap, raster value < 1.

Reference: https://doi.org/10.3390/app11062865

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Knowledge gap analysis of geothermal gradient data.

Density map of geothermal gradient developed with the "point density" algorithm of ArcGIS®. Pixel value, number of data per 100,000 km2. Parameters: population field, none; cell size, 5000; radius, 178,415 metres; areal units, square kilometres; method, geodesic. Knowledge gap, raster value < 1.

Reference: https://doi.org/10.3390/app11062865

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Knowledge gap analysis of seafloor temperature data

Density map of seafloor temperature developed with the "point density" algorithm of ArcGIS®. Pixel value, number of data per 100,000 km2. Parameters: population field, none; cell size, 5000; radius, 178,415 metres; areal units, square kilometres; method, geodesic. Knowledge gap, raster value < 1.

Reference: https://doi.org/10.3390/app11062865

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0 Geological and geochemical evicence and indicators

Evidence and indicators for gas hydrates. Point data.

Geological and geochemical evidence and indicators for gas hydrates. Represented as points. For further information see info-tab

Evidence and indicators for gas hydrates. Polygons.

Geological and geochemical evidence and indicators for gas hydrates. Polygons. For further information see info-tab.

Gas analyses from IODP Drilling holes

Gas analyses from IODP drilling holes

0 Geophysics

Geophysical indicators. Point data

Geophysical indicators for the presence of gas hydrate. Point data. For further information see info-tab

Geophysical indicators for gas hydrates. Lines.

Geophysical indicators for the presence of gas hydrate. Profiles. For further information see info-tab

Geophysical indicators for gas hydrates. Polygons

Geophysical indicators for the presence of gas hydrate. Polygons. For further information see info-tab

0 Fluid flow indicators

Seafloor features that indicate fluid flow. Point data.

Auto generated data set

Seafloor features that indicate fluid flow. Polygons.

Auto generated data set

0 GHSZ

Base of negative bouyancy zone for 96% C02. South of Biscay Bay, Galicia Area