-
mmmll
Report for DG JRC in the Context of Contract
JRC/PTT/2015/F.3/0027/NC “Overview of shale layers characteristics
in Europe relevant for assessment of unconventional resources”
European Unconventional Oil and Gas Assessment
(EUOGA)
Overview of shale layers characteristics in Europe relevant for
assessment of unconventional
resources
Appendix Volume
Deliverable T6b
-
Overview of shale layers characteristics in Europe
Delivery T6b. Appendix Volume A-D February 2017 31
Table of Contents Table of Contents
.............................................................................................31
Appendix A Shale layer overview
........................................................................33
Appendix B Shale layer characteristics for EUOGA shales
.......................................46 Appendix C Shale layer
characteristics for reference shales
.................................. 131 Appendix D Bibliography of
European shale layer relevant literature .....................
151
-
Overview of shale layers characteristics in Europe
Delivery T6b. Appendix Volume A-D February 2017 32
This report is prepared by Niels H. Schovsbo with contributions
from Karen L. Anthonsen, Christian B. Pedersen, and Lisbeth
Tougaard, all from the Geological Survey of Denmark and Greenland
(GEUS), as part of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET. The analyses, interpretations
and opinions expressed in this report represent the best judgments
of the Geological Survey of Denmark and Greenland (GEUS). This
report assumes no responsibility and makes no warranty or
representations as to the productivity of any oil, gas or other
mineral well. All analyses, interpretations, conclusions and
opinions are based on observations made on material supplied by the
European National Geological Surveys (NGS’s) in 2016. The
information and views set out in this study are those of the
authors and do not necessarily reflect the official opinion of the
Commission. The Commission does not guarantee the accuracy of the
data included in this study. Neither the Commission nor any person
acting on the Commission’s behalf may be held responsible for the
use which may be made of the information contained therein. No
third-party textual or artistic material is included in the
publication without the copyright holder’s prior consent to further
dissemination and reuse by other third parties. Reproduction is
authorised provided the source is acknowledged. All will presented
in here will be available through an interactive Web-GIS
application hosted at the European Commission's science and
knowledge service, the Joint Research Centre (JRC-IET). Citation to
this report is: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS. Appendix Volume.
The report is the final version (revision 0) issued in February
2017 and replaces previous issued T6a reports.
-
Overview of shale layers characteristics in Europe
Delivery T6b. Appendix Volume A-D February 2017 33
Appendix A Shale layer overview
-
CP index Shale Name Age
1001 Zebrus Lower Ordovician
1002 Raikiula‐Adavere Llandovery (Early Silurian)
1003 Fjäcka‐Mossen (Oandu‐Vormsi)
Late Ordovician (Katian)
1004 Lemeš
Late Jurassic (Kimmeridgian ‐Tithonian) 1005
Meride Fm (Besano Fm and Perledo mob)
Ladinian1006
Riva di solto shales (lower lithozone)
Norian1007 Marne di Bruntino Aptian‐Albian1008
Emma limestones Upper Triassic‐Lower Jurassic1009
Marne di Monte Serrone Jurassic (Toarcian)1010
Marne a Fucoidi Cretaceous (Aptian‐Albian)
1011 Argille Lignitifere Tortonian‐Messinian1012
Noto Shale Rhaetian1013 Streppenosa Shale
Norian‐Rhaetian‐Hettangian
1014 Alum Shale Formation
M. Cambrian‐E. Ordovician1015
Alum Shale Formation
M. Cambrian‐E. Ordovician
1016 Alum Shale Formation
M. Cambrian‐E. Ordovician1017
Alum Shale Formation
M. Cambrian‐E. Ordovician1018 Mikulov Marl
Malmian (Upper Jurassic)1019
Alum Shale Formation
M. Cambrian‐L Ordovician1020
Catalonian Chain Carboniferous Carboniferous2021
Iberian Lower Cretaceous Lower Cretaceous1022
Iberian Carboniferous Carboniferous1023
Duero Carboniferous Carboniferous1024 Ebro Carboniferous
Carboniferous1025 Ebro Eocene Eocene1026
Guadalquivir Carboniferous Carboniferous1027
Basque‐Cantabrian Liassic
Lower Jurassic (Liassic)1028
Basque‐Cantabrian Lower Cretaceous
Lower Cretaceous1029
Basque‐Cantabrian Upper Cretaceous
Upper Cretaceous1030 Basque‐Cantabrian Carboniferous
Carboniferous1031 Cantabrian Massif Carboniferous
Carboniferous1032 Pyrenees Liassic
Lower Jurassic (Liassic)1033
Cantabrian Massif Silurian Silurian1034
Pyrenees Lower Cretaceous Lower Cretaceous1035
Pyrenees Eocene Eocene1038
Tandarei graptolitic black shales
U Ordovician U Silurian L Devonian1039
Calarasi bituminous limestones
U Devonian‐ L Carboniferous1040
Vlasin black shale Formation
U Carboniferous1041 Biogenic shale U Badenian1042
Biogenic shale L Sarmatian
1043 East Ukraine shales
Carboniferous to Permian1045
Westphalian A and B Formations
Westphalian A and B (Early‐Pennsylvanian)1046
Chokier shales Namurian (U‐Mississippian)1047
Chokier alum shales Namurian (U‐Mississippian)1048
Chokier & Souvré hot shales
Namurian (U Mississippian)1049 Kössen Marl
Upper Triassic, Late Norian to Rhaetian1050
Tard Clay Oligocene1051 Lower Palaeozoic shales
Upper Cambrian to Llandovery 1052
Lower Palaeozoic shales
Upper Cambrian to Llandovery
1053 Lower Palaeozoic shales
Silurian (Llandovery to Wenlock)
1054 Lower Palaeozoic shales
Silurian (Llandovery to Wenlock)1055
Upper Palaeozoic shales Carboniferous
1056 Lower Paleozoic shales
Silurian to Lower Devonian
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 34
-
CP index Shale Name Age
1057Upper Paleozoic shale & coal succession Trigorska & Konarska Fms
Lower carboniferous (Middle Mississippian, Upper Visean)
1058J1 shale & clay limestones Ozirovo Fm (Bucorovo & Dolnilucovt Mbs)
Jurassic (Sinemurian ‐ Toarcian)
1059
J2 shale Etropole Fm (Stefanets Mb)
Aalenian Lower Bajocian
1060Oligocene shale Ruslar Fm (equivalent of Maykop Fm)
Oligocene
1061 Upper Ordovician‐Llandovery Shales
Late Ordovician – Silurian (Llandovery)1062
Black shale Lower Silurian1063 Mikulov Marl
Malmian (Upper Jurassic)
1064 Geverik Shale Member Namurian A1065
Posidonia Shale Formation Toarcian (Jurassic)
1066 Haloze‐Špilje Fm. Shale
Neogene: Karpatian and Badenian
1067 Haloze‐Špilje Fm. Shale
Neogene: Karpatian and Badenian
1068 Haloze‐Špilje Fm. Sandstone
Neogene: Karpatian and Badenian
1069 Haloze‐Špilje Fm. Sandstone
Neogene: Karpatian and Badenian
1070 Kimmeridge Clay U. Jurassic1071
Limestone Coal Formation
Carboniferous (Pendleian)1072
West Lothian Oil Shale unit Carboniferous1073
Lower Limestone Formation Carboniferous
1074 Mid Lias Clay Jurassic
1075 Oxford Clay U. Jurassic (Oxfordian)
1076 Upper Lias Clay Jurassic1077
Bowland ‐Hodder unit Carboniferous
1078 Corallian Clay Jurassic (Oxfordian)1079
Gullane Unit Carboniferous1080 Permo‐carboniferous shales
Westphalian to Autunian1081 Autunian shales
Permian1082 Promicroceras Shales Jurassic, Sinemurian1083
Amaltheus Shales Jurassic, Pliensbachian1084
Schistes Cartons Fm Jurassic, Toarcian1085
Sainte Suzanne Marls Bedoulian' = Aptian
1086 Myslejovice Fm. (Culm)
L. Carboniferous (Visean)1087 Lias shales
Jurassic2012 Posidonia Lower Jurassic2013 Alaunschiefer
Carboniferous
2001 Alum Shale Formation
M. Cambrian‐L Ordovician2002 Marcellus Devonian
2003 Haynesville Late Jurassic
2004 Bossier Late Jurassic
2005 Barnett Mississippian
2006 Fayetteville Mississippian
2007 Muskwa Devonian
2008 Woodford Devonian
2009 Eagle Ford Cretaceous
2010 Utica Ordovician
2011 Montney Triassic
2014 Mean EUOGA2016
Mean L. Palaeozoic EUOGA shale2017
Mean Carboniferous EUOGA shale2018
Mean Jurassic EUOGA shale2015
Mean N. American Shales2019 Antrim Devonian
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 35
-
CP index
1001
1002
1003
1004100510061007100810091010
101110121013
10141015
1016101710181019102020211022102310241025102610271028102910301031103210331034103510381039104010411042
104310451046104710481049105010511052
1053
10541055
1056
Basin Structural setting
Baltic
Foreland basin setting. Structural setting simple
Baltic
Foreland basin setting. Structural setting simple
Baltic
Foreland basin setting. Structural setting simple
Dinaric Mts.
Outer Dinarides, Intraplatform shallow throughLombardy
Passive margin; synrift extensional tectonicLombardy
Passive margin; synrift extensional tectonicLombardy
Passive margin; synrift extensional tectonicEmma Basin
Passive margin; synrift extensional tectonicUmbria‐Marche Basin
Passive margin; synrift extensional tectonicUmbria‐Marche Basin
Passive margin; synrift extensional tectonic
Ribolla Basinextensional tectonic; opening of the Tyrrhenian basin
Ragusa Foreland basinRagusa Foreland basin
Baltic
gently dipping succession to the south‐south‐eastSorgenfrei Tornquist Zone
complex. Inversion in L. Cretaceous
Danish Basin, Höllviken Half grabenForeland basin, Complex Variscan and Alpine wrench faulting
Fennoscandian Shield Shield platformVienna Basin
Passive marginNorwegian‐Danish
Passive margin; synrift extensional tectonicCatalonian Chain
High complexityIberian Medium complexityIberian
High complexityDuero High complexityEbro
High complexityEbro Low complexityGuadalquivir
High complexityBasque‐Cantabrian
Medium complexityBasque‐Cantabrian
Medium complexityBasque‐Cantabrian
Medium complexityBasque‐Cantabrian
High complexityCantabrian Massif
High complexityPyrenees
Medium complexityCantabrian Massif
High complexityPyrenees Medium complexityPyrenees
Low complexityMoesian Platform
foreland basinMoesian Platform
foreland basinMoesian Platform
foreland basinTransilvanian back‐arc basinTransilvanian
back‐arc basinDniprovsko‐Donetska Depression, south‐eastern part
south‐eastern part of Dniprovsko‐Donetska Depression
Campine Basin Foreland basinMons Basin
Foreland basinLiège Basin
Variscan orogenic front and forelandCampine Basin
low to moderateZala BasinHungarian PaleogeneBaltic Basin (assessment area 1)
simplePłock‐Warsaw zone (assessment area 2)
simplePodlasie Basin and North Lublin Basin (assessment area 3)
simple to complexSouth Lublin Basin and Narol Basin (assessment area 4)
complexFore‐Sudetic Monocline (assessment area 5)
complexMoesian Platform, Structural unit: North Bulgarian Uplift
extensional ‐ passive margin
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 36
-
CP index
1057
10581059
1060
106110621063
10641065
1066
1067
1068
1069
1070107110721073
1074
1075
10761077
10781079108010811082108310841085
1086108720122013
20012002
2003
2004
2005
2006
2007
2008
2009
2010
2011
201420162017201820152019
Basin Structural setting
Moesian Platform‐North Bulgarian Uplift, Alexandria depression, Southern Dobudja
extension (orogeny collapse) Moesian Platform ‐ Moesian Platform & Fore Balkan
extension (Passive margin)Moesian Platform and fore Balkan
extension (Passive margin)
Kamchia basin (part of Black Sea basin)
compression (Fore deep)
Baltic
foreland basin setting; structural complexity lowLviv‐Volyn Vienna Basin; SE Bohemian Massif
Passive margin
Northwest European Carboniferous BasinWest Netherlands Basin/Broad 14s Basin
Large amounts of faults, some inverse tectonicsGas mature part Mura‐Zala Basin (NW part of the Pannonian basin System
Sub‐basins (depressions) and inverse antiformsOil mature part of Mura‐Zala Basin (NW part of the Pannonian basin System
Sub‐basins (depressions) and inverse antiformsGas mature part Mura‐Zala Basin (NW part of the Pannonian basin System
Sub‐basins (depressions) and inverse antiformsOil mature part of Mura‐Zala Basin (NW part of the Pannonian basin System
Sub‐basins (depressions) and inverse antiforms
Weald Basin, SE EnglandMidland Valley, ScotlandMidland Valley, ScotlandMidland Valley, Scotland
Weald Basin, SE England
Weald Basin, SE England
Weald Basin, SE EnglandNorthern England
Weald Basin, SE EnglandMidland Valley, ScotlandParis Basin, Lorraine, Alsace, South‐East Basin
Post‐orogenic distensive basinsAutun
Post‐orogenic distensive basinsParis Basin
Sag basinParis Basin
Sag basinParis Basin, Jura, South‐East
sag & syn‐riftAquitaine Basin
post‐rift series
Culm Basin; SE Bohemian Massif
Variscan syntectonic foreland basin ‐ compressional setting during and shortly after deposition
LusitanianGermanyGermany
Norwegian‐Danish
Passive margin; synrift extensional tectonicAppalachian
East Texas ‐ North Louisiana
East Texas ‐ North Louisiana
Forth Worth
Arkoma
Horn River
Arkoma
Eagle Ford
St Lawrence
Western Canada
Michigan‐Biogenic
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 37
-
CP index
1001
1002
1003
1004100510061007100810091010
101110121013
10141015
1016101710181019102020211022102310241025102610271028102910301031103210331034103510381039104010411042
104310451046104710481049105010511052
1053
10541055
1056
Facies variability Country
1. Area extend
Offshore Onshore
High Lateral continuity; facies variability moderate
Latvia 3100 100 3000
High Lateral continuity; facies variability moderate
PL, LT, LV, EE, DK 16000 5000 11000
High Lateral continuity; facies variability moderate
LT, LV, PL, DK 15300 5000 10500
Moderate lateral continuity and facies variability.
Croatia 39
39High lateral and vertical variability.
IT, SW 7743 0
7743High lateral and vertical variability.
Italy 5500 0
5500High lateral and vertical variability.
Italy 4069 0
4069High lateral and vertical variability.
Italy 9365 5977
3388High lateral and vertical variability.
Italy 20792 11813
8979High lateral and vertical variability.
Italy 20791 11810 8981
High lateral and vertical variability. Italy
5564 0 5564Medium facies variability Italy 5090 1190
3900Medium facies variability Italy 12600 8535 4065
Inner and outer shelf black shale with anthraconite and limestone interbeds
Sweden 10227 10121
106Outer shelf black shale with some limestone and antraconite interbeds
Sweden 2835 450 2385
Outer shelf black shale with some limestone and antraconite interbeds
Sweden 1610 1106
504Inner black shale with limestone and antraconite interbeds
Sweden 1497 1497Low lateral variability A, CZ 729
729Lateral continuity high and facies variability low.
Denmark 29695 15902 13793
Spain 500 500Spain 675 675Spain 750 750Spain 800 800Spain 750
750
High laterally variability Spain 75
75High vertically. Lateral continuity high.
Spain 650 650Laterally continuous Spain 2350 2350
Spain 1800 1800Spain 1050 1050Spain 375 375
High vertically variability Spain 1500
1500Laterally continuous Spain 500 500
Spain 500 500Spain 200 200
High laterally variability Spain 575
575Lateral variability Romania, Bulgaria
Romania, BulgariaLateral variability
Romania, BulgariaLateral variability Romania
20000Lateral variability Romania 20000
Moderate lateral consistence and facial variability
Ukraine 10500 10500Low to moderate variability
Belgium, Netherland 708 708Complex BelgiumModerate
Belgium (Wallonia) 16 16
Belgium, Netherland 1812 1812Hungary 720Hungary 7800
Lateral continuity Poland 17821
17821Lateral continuity Poland 4599 4599
Lateral continuity Poland 8703 8703
Lateral continuity Poland 8465
8465High lateral and vertical variability.
Poland 13179 13179
Lateral continuity Bulgaria and Romania 1100
1100
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 38
-
CP index
1057
10581059
1060
106110621063
10641065
1066
1067
1068
1069
1070107110721073
1074
1075
10761077
10781079108010811082108310841085
1086108720122013
20012002
2003
2004
2005
2006
2007
2008
2009
2010
2011
201420162017201820152019
Facies variability Country
1. Area extend
Offshore Onshore
Lateral continuity Bulgaria and Romania 12500
12500
lateral and vertical continuity Bulgaria 10000
10000lateral and vertical continuity Bulgaria 11000
11000
Lateral continuity Bulgaria 2110 210
1900lateral continuity high and facies variability low; vertical variability moderate
Lithuania 14800 5000 10000Marine ‐deep marine Ukraine
30669 0 30669low (basinal facies) CZ 1600 0
1600Mudstones with sandstone intercalations, recurring cycles of delta progradation. Reasonable correlatability
Netherlands 21232 12703
8529Low; correlatable over entire Dutch on‐ and offshore
Netherlands 12400 6240 6160
Vertical and lateral; moderate to high Slovenia, Austria, Hungary, Croatia
914 914
Vertical and lateral; moderate to high Slovenia, Austria, Hungary, Croatia
1230 1230
Vertical and lateral; moderate to high Slovenia, Austria, Hungary, Croatia
914 914
Vertical and lateral; moderate to high Slovenia, Austria, Hungary, Croatia
1230 1230
UKUKUKUK
UK
UK
UKUK
UKUK
High lateral variability (fluvio‐lacustrine settings)
France 0
35000High lateral variability (fluvio‐lacustrine settings)
France 0 250Facies variability very low France 0
47000Facies variability very low France 0
21000Facies variability: Lateral continuety high and facies variability low.
France, Germany 0
105000Facies variability: Lateral continuety high and facies variability low.
France 0 2800
moderate to low Cz 1000PtGermanyGermany
Lateral continuity high and facies variability low.Summary of 1014, 1016, 1019North America
246049 246049
North America 23310 23310
North America 23310 23310
North America 12950 12950
North America 23310 23310
North America 38850 38850
North America 28490 28490
North America 19425 19425
North America 6475 6475
North America 64750 64750
Europe 6490 4489 5200Europe 9773 4668 7439Europe 4662 12703
3755Europe 6025 4513 3446North America 48692 0
48692North America
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 39
-
CP index
1001
1002
1003
1004100510061007100810091010
101110121013
10141015
1016101710181019102020211022102310241025102610271028102910301031103210331034103510381039104010411042
104310451046104710481049105010511052
1053
10541055
1056
2. Gros thickness
2a. Net thickness
2b. % Net/Gross
3. Avg. Depth
4. Density 5. TOC 6. Porosity
7. Maturity 8. Res. Pres.
9. Res. Temp.
37 1572 1,9 41
50 25 45 1700 2,47 4,2 5,7 0,87 1668 72
16 8 45 1800 2,53 3,2 5,7 0,80 1668 71
350 37 9 465 2,65 6,0 4,2 0,60250 25 10 5726 0,9 1,28200 5000
1,3 4,00
80 10 13 2500 1,0250 15 6 6000 4,7
13 5000 1,020 4500 1,8
40 8 20 1000 20,0 1,10275 20 7 2900 4,0
1510 20 1 3500 0,8
25 20 80 300 11,0 0,61 435 1580 76 95 800 2,54 7,5 6,1 2,29
28
40 40 100 2300 3,0020 16 80 30 11,0 0,60
525 5500 2,24 2 5,0 1,20 13900 15055 50 95 4250 2,45 9,0 7,0
1,60 7106 135
75 1500 2,40105 600 2,10 0,5 1,05
75 1500 2,3575 1700 2,3075 2825 2,35 1,0 1,5038 2400 2,1575 1500
2,45 3,7 1,60
120 63 52 2200 2,15 2,52000 125 6 1700 2,25 1,0
125 2000 2,1538 1200 2,35
275 3000 2,35185 115 62 3000 2,35 0,6 1,09
70 2500 2,1585 1000 2,1560 2000 2,15 1,3
625 2,11250 1,2
50011001400
2800 400 14 4500 2,67 1,8 3,0 1,50 6527 119515 30 6 1869 5,5
2,35 2786 62
75 1750 105 1650
70 70 100 1838 2,38 8,2 1,6 3,09 1420 84200 200 100 2500 2,5 3,9
2 0,34 3225 165
68 27 40 2150 2,50 2.21 10,0 0,48 3480 13065 40 62 2800 2,60 3,0
4,5 1,30 4100 7450 50 100 4430 2,60 2,8 4,5 3,00 6500 129
130 40 31 2025 2,60 2,8 4,5 1,30 3000 68
120 30 23 2995 2,60 2,5 4,5 2,00 4400 80430 55 12 2500 2,60 2,6
3,6 1,50 4000 85
1350 540 40 2200 2,40 1,8 2,0 1,60 4200 100
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 40
-
CP index
1057
10581059
1060
106110621063
10641065
1066
1067
1068
1069
1070107110721073
1074
1075
10761077
10781079108010811082108310841085
1086108720122013
20012002
2003
2004
2005
2006
2007
2008
2009
2010
2011
201420162017201820152019
2. Gros thickness
2a. Net thickness
2b. % Net/Gross
3. Avg. Depth
4. Density 5. TOC 6. Porosity
7. Maturity 8. Res. Pres.
9. Res. Temp.
1100 495 45 2250 2,35 1,8 2,8 1,10 4750 110
150 68 45 3500 2,40 1,2 3,0 0,80 5200 122100 60 60 3350 2,30 1,4
2,8 0,75 4800 110
600 355 60 250 2,30 2,1 3,3 0,40 350 18
50 20 40 1800 2,49 4,1 5,7 0,85 1668 712296 1504 65 2821 2,70
1,1 4,4 2,50
650 650 100 5500 2,52 1,9 4,4 0,70 4786 150
50 50 100 3700 2,71 2,0 1,5 2,50 370 12530 27 90 2000 5,7 7,0
0,80 5880 78
685 685 100 2900 2,30 1,0 2,0 1,29 4500 130
660 660 100 2800 2,30 1,0 2,0 0,86 4500 130
365 365 100 2900 2,30 1,0 9,5 1,29 5000 147
355 355 100 2800 2,30 1,0 9,5 0,86 5000 147
2,60 10,9 0,601151 2,60 4,1 1,101050 2,60 2,7 1,101016 2,60 3,1
1,10
20 2,60 1,2 0,60
30 2,60 6,4 0,60
20 2,60 3,0 0,602,60 1,8 3263
27 2,60 0,601570 2,60 2,2 1,10
200 1000 1,0 440,001000 45 5 300
25 0,720 3,040 13 0 800 4,0 440,00
600 1,5
1250 250 20 7000 2,68 11,3 13,0 2,20 10287 2104,1 10,0 1,15
60 2,40 4,3 11,8 1,17260 2,70 3,0 10,1 2,21
90 90 95 4250 2,45 9,0 7,0 2,00 7106 13558 46 79 3810 4,0 6,2
1,50
79 79 100 3658 3,0 8,3 1,50
85 75 88 3551 1,6 7,5 1,50
244 91 38 2286 3,7 5,0 1,60
55 41 75 1737 3,8 6,0 2,50
128 122 95 2438 2,2 4,0 2,00
152 50 33 2896 5,3 5,0 1,50
70 69 98 2134 2,8 10,0 1,20
229 152 67 1311 1,3 2,00
366 107 29 1829 2,0 5,0 1,60
481 148 49 2696 2,44 3,5 4,4 1,34 4093 94356 195 68 2171 2,51
4,7 4,8 1,71 3926 74627 146 46 2128 2,50 3,1 3,8 1,67 3302 97268
181 39 3244 2,50 5,5 4,7 0,78 8189 126147 83 70 2565 3,0 6,3
1,69
37 458 10,0 8,5 0,65 400 24
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 41
-
CP index
1001
1002
1003
1004100510061007100810091010
101110121013
10141015
1016101710181019102020211022102310241025102610271028102910301031103210331034103510381039104010411042
104310451046104710481049105010511052
1053
10541055
1056
10. Gas saturation
11. Oil Saturation
12. HI 13. Ker. type
14. Sorption capacity @ Vr 1,9 %
15. Matrix permeability
II
302 II, II‐III 100
262 II, II‐III
556 IIS610 II‐III251 II‐III
54 II‐III47 I, IIS
6 II‐III17 II‐III
412 II125 III
358 II21 4 II
II513 II300 II‐III 5,1
50 0 470 I , II 0,2 40257 II, III
2 II
II, IIIII‐III
257 II, III
14 IV
31355 I
658III
20 30 ІІ, ІІІ 0,15 0,01II‐III
II70 516 II S
252 II, III67 6 100 II67 6 100 II
67 6 200 II
67 6 200 II55 III, II‐III 90
II, III
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 42
-
CP index
1057
10581059
1060
106110621063
10641065
1066
1067
1068
1069
1070107110721073
1074
1075
10761077
10781079108010811082108310841085
1086108720122013
20012002
2003
2004
2005
2006
2007
2008
2009
2010
2011
201420162017201820152019
10. Gas saturation
11. Oil Saturation
12. HI 13. Ker. type
14. Sorption capacity @ Vr 1,9 %
15. Matrix permeability
II, II‐III, III
5 I, I‐II4 I‐II
4 II
297 II, II‐III 0,0001
50 570 II
20 II 34023 II
210 III, II 50
210 III, II 50
50 210 III, II 1000
50 210 III, II
1000I with minor II,
III3 117,5 I, III, minor II3 346
I, III, minor II3 73,5
I, III, minor II
I with minor II, III
I with minor II, III
I with minor II, III
3 74,2 II, IIII with minor II,
III3 265 I, III, minor II
I70 I
IIII
625 IIII
20 350 III‐IIII
179 II58 III‐II
50 0 10 II 0,2 40
55 1 20 II 20
75 1 14 II 350
45 1 15 II 10
45 10 45 II 50
60 1 15 II 50
80 1 10 II 20
40 5 60 II 25
75 15 80 II 1000
60 5 27 II 10
90 1 17 II 30
29 5 240 II 0,175 8956 5 255 II 0,2 7014 164 II‐II/III 0,15
14337 322 II 563 4 30 II 15744
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 43
-
CP index
1001
1002
1003
1004100510061007100810091010
101110121013
10141015
1016101710181019102020211022102310241025102610271028102910301031103210331034103510381039104010411042
104310451046104710481049105010511052
1053
10541055
1056
16. Adsorbed gas storage capacity
17. Compressibility factor (z)
18. Bg Gas formation volume factor
19. Langmuir Pressure
20. Langmuir Volume
Total clay Total quartz‐feldspars
Total carbonate
1,01 435 36 56 33 11
56 33 11
0 4 96
71 23 6
54 37 8
53 46 131 16 53
50 1,01 0,0133 435 36 51 38 10
66 31 3
45 0,85 0,0150 395 30 80 15 573 20 7
24 61 1531 11 5848 14 38
44 1,00 0,0043 51 41 844 1,00 0,0032
44 1,00 0,0058
44 1,00 0,004144 1,00 0,0046 49 46 5
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 44
-
CP index
1057
10581059
1060
106110621063
10641065
1066
1067
1068
1069
1070107110721073
1074
1075
10761077
10781079108010811082108310841085
1086108720122013
20012002
2003
2004
2005
2006
2007
2008
2009
2010
2011
201420162017201820152019
16. Adsorbed gas storage capacity
17. Compressibility factor (z)
18. Bg Gas formation volume factor
19. Langmuir Pressure
20. Langmuir Volume
Total clay Total quartz‐feldspars
Total carbonate
1,01 435 36 56 33 11
49 10 42
33 0,0212 5 69 2681 0,0195
51 23 26
51 23 26
16 77 7
16 77 7
34 43 2344,5 59 32 944,5 59 32 944,5 59 32 9
34 43 23
34 43 2344,5 0,0211 906,25 44,5
34 43 2344,5 59 32 9
1290 169,5 53 19 283916 98 33 46 21
50 1,01 0,0130 435 36 51 38 1036 38 26
38 38 25
51 32 18
29 53 18
45 41 14
22 67 11
25 69 6
17 17 67
27 41 32
18 47 35
47 0,98 0,0112 1230 69 47 32 2145 1,00 0,0061 435 36 53 39 843
0,93 0,0155 1739 58 50 39 1181 0,0195 1290 170 34 28 39
31 44 2540 40 20
Appendix A Shale layer overview Overview of shale layers
characteristics in Europe
Delivery T6b. Appendix Volume February 2017 45
-
Overview of shale layers characteristics in Europe
Delivery T6b. Appendix Volume A-D February 2017 46
Appendix B Shale layer characteristics for EUOGA shales
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: No name (local lithostratigraphical unit - Zebrus
Formation)
1001
Age: Lower Ordovician Tremadocian Stage Basin: Baltic Basin
Structural setting
Facies variability no dataCountry: Latvia 1. Area extend
(km2)
Offshore 100 aproximate Onshore 3000 triangular aproximate
2. Thickness (gross, m) 26 48 37 triangular2a. Thickness (net,
m) not calculated2b. Net/Gross (%) no data
3. Depth (m) 1474 1670 1571,8 triangularmeasured depth, top of
the
Formation
4. Density (g/cm3) no data
5. TOC (%) 1,91 1,91 1,91 triangular 1
6. Porosity (%) no data
7. Maturity (%VR) or graptolite equivalent no data
8. Reservoir pressure (psi) no data
9. Reservoir Temperature (°C) 23 58 40,5 triangular obtained
from log data
10. Gas saturation (%)(Sg) no data
11. Oil Saturation (%) So) no data
12. Gas generation mgHC/g TOC (Hydrogen index) no data
13. Kerogen type II 2
14. Sorption capacity VReq. - 1,9 % (mmol/g) no data
15. Matrix permeability (nDarcy) no data
16. Adsorbed gas storage capacity (scf/ton) no data
17. Compressibility factor (z) no data
18. Bg - Gas formation volume factor no data
19. Langmuir Pressure (pL, psi) no data
20. Langmuir Volume (nL, scf/ton) no data
Bulk mineral constituents XRD % Source
Average clay content (%)
Average quartz-feldspars content (%)Average carbonate content
(%) M
iner
alog
y
Compiled by Baiba Brikmane, Inga Piese. Supervised by Daiga
Pipira
REFERENCE LIST : 1 . Kanev S.V. 1995. Geochemical
Studies.Hydrocarbon Sector Support Project, Phase IIa (HSSP/IIa).
2. Kanev S., Margulis L., Bojesen-Koefoed J.A., Weil W.A., Merta
H., Zdanaviciute O. 1994. Oil and hydrocarbon source rocks of the
Baltic Syneclise. Oil & Gas Journal, July 11, 1994.
Available:http://mapx.map.vgd.gov.lv/geo3/VGD_OIL_PAGE/_private/article_1994.pdf
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 47
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Raikiula-Adavere1002
Age: Llandovery (Early Silurian)
Basin: Baltic Sedimentary Basin
Structural setting: Foreland basin setting. Structural setting -
simple
Facies variability: Lateral continuity high and facies
variability homogenouse. Horizontal (vertikal) variability -
moderate.
Country: PL, LT, LV, EE, DK 1. Area extend (km2) 10254 21823
16000 Lognorm 1
Offshore 3206 6413 5000 Lognorm 2
Offshore area comprises maximal area of the Lithuanian Baltic
sea territory where the shale is widspread. Minumum area has been
considerd as half of total offshore area.
Onshore 7613 15410 11000 Lognorm 1
2. Thickness (gross, m) 15 80 50 Lognorm 1, 9, 10 Thickness is
for net thickness of Llandovery shale
2a. Thickness (net, m) 7 45 25 Lognorm 22b. Net/Gross (%) 35 55
45 Lognorm
3a. Depth (m), top 1500 2045 1600 1, 9, 10
3b. Depth (m), bottom 1500 2120 1800 Lognorm 1, 9, 10Depth grid
is of the depth of the bottom of Llandovery (Early Silurian)
shale
4. Density (g/cm3) 2,17 2,85 2,47 Lognorm 1, 2
Grain density values based on measurements. Wt % from QuantaETC
(QXRD) and TOC obtained from RockEval and converted into the volume
percent (vol.%) of the solid matrix constituents. Number of
measurements - 91. Uncertainty - 20%.
5. TOC (%) 2 19,2 4,2 Lognorm 1, 2, 5,6,10
6. Porosity (%) 1,2 14,1 5,7 Lognorm 1,2
7. Maturity (%VR) or graptolite equivalent 0,48 1,94 0,87
Lognorm 1, 2, 4, 5,6
Vitrinite-like particles + graptolites+ bitumines calibrated to
Vitrinite reflectance
8. Reservoir pressure (psi) 1450 1886 1668 triangular 2,7
Sparse mesurement data converted from MPa. Mean pressure
gradient (Baltic region) 0.453 psi/ft. No overpressure
indications.
9. Reservoir Temperature (°C) 32 90,2 71,7 triangular 2
Temperature mesurements at certain depth data. Mean present day
geothermal gradient in Lithuania 25 °C/km. Present day geothermal
gradient in geothermal anomaly in Western Lithuania - 40-45
°C/km.
10. Gas saturation (%)(Sg) n/a n/aNo production data available.
Polish Silurian shales would be the best analogue.
11. Oil Saturation (%) So) n/a n/a
No production data available. Test Llandovery oil obtained in 2
wells. Polish Silurian shales would be the best analogue.
12. Gas generation mgHC/g TOC (Hydrogen index) 89 720 302
triangular 1, 5,6
Values based on 332 RockEval and Leco measurements. Uncertainty
- 15%.
13. Kerogen type II, II-III 1,5,6,10Kerogen type values based on
290 RockEval measurements. Uncertainty - 15%.
14. Sorption capacity VReq. - 1,9 % (mmol/g) n/a n/a
No measurement data. Analogue numbers could be form Furongian
unit of Alum Shale or Polish Silurian shales.
15 Matrix permeability ( nDarcy ) 85 400 100 Lognorm 1,2
Matrix permeability values based on 7 GRI-derived absolute Kg
determined from pressure decay results and 27 helium permeameter
measurements (Soviet uncertificated equipment). Uncertainity -
70%
16. Adsorbed gas storage capacity (scf/ton) n/a n/a
No measurement data. Analogue numbers could be form Furongian
unit of Alum Shale or Polish Silurian shales.
17. Compressibility factor (z) 0.76 1,1 1,01
No measurement data. Analogue numbers are form Furongian unit of
Alum Shale, or could be from Polish Silurian shales.
18. Bg - Gas formation volume factor n/a n/a
Bo - Oil formation volume factor n/a n/aNo data available.
Polish Silurian shales would be the best analogue.
19. Langmuir Pressure (pL, psi) 432 700 435 8
No data available. Analogue numbers are form Furongian unit of
Alum Shale, or could be from Polish Silurian shales.
20. Langmuir Volume (nL, scf/ton) 20 63 36 8
No data available. Analogue numbers are form Furongian unit of
Alum Shale, or could be from Polish Silurian shales.
Bulk mineral constituents XRD % Source1,2
Average clay content (%) 49Average quartz-feldspars content (%)
29Average carbonate content (%) 10
TOC values based on 332 RockEval measurements. Uncertainty - 5%.
Porosity valuse based on 37 mesurements: 7- GRI-
Min
eral
ogy
REFERENCE LIST : 1 . Investigations of structure and composition
of shaley Lower Paleozoic succession in Lithuanian part of the
Baltic Sedimentary Basin. Report of Lithuanian Geological Survey,
Lazauskiene et al., 2014, 132 pp (in Lithuanian). 2. Lazauskiene,
J., Bitinas, J.,
- Excel sheet with parameters for data distribution. 3. Genesis
of Shale Geological Formations and Hydrocarbon Extraction: Impact
on environment and human health. 2014-12-02, 56 pp.
http://skalunudujos.lt/wp-content/uploads/2014-12-02_Genesis_of_shale_geological-formations_LMA-website.pdf.
4. Petersen, H.I., Schovsbo, N.H., Nielsen, A.T., 2013. Reflectance
measurements of zooclasts and solid bitumen in Lower Palaeozoic
shales, southern Scandinavia: correlation to vitrinite reflectance.
International Journal of Coal Petrology 114, 1–18.
http://www.sciencedirect.com/science/article/pii/S0166516213001080
52009.Organic matter of Early Silurian succession – the potential
source of unconventional gas in Lithuania. Baltica. Vol. 22, No. 2.
89-98.. 62007. The Petroleum potential of the Silurian succession
in Lithuania. Journal of Petroleum Geology. 325-337. 7. EIA/ARI
World Shale Gas and Shale Oil Resource Assessment, Technically
Recoverable Shale Oil and Shale Gas Resources: An Assessment of 137
Shale Formations in 41 Countries Outside the United States
http://www.eia.gov/analysis/studies/worldshalegas/pdf/fullreport.pdf
8. Matus Gasparik, Pieter Bertier, Yves Gensterblum, Amin
Ghanizadeh, Bernhard M. Krooss, Ralf Littke, Geological controls on
the methane storage capacity in organic-rich shales - April 2013 9.
Lapinskas P. 2000. Structure and petroleum potential of the
Silurian in Lithuania. Vilnius, 203 p.(in Lithuanian). 10. K.
(reds.). 2001. Petroleum Geology of Lithuania and Southeastern
Baltic. Vilnius. 204 p.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 48
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution Source (Ref.list) Comments
Shale Name: Fjacka-Mossen (Oandu-Vormsi)1003
Age: Late Orodovician (Katian)Basin: Baltic Sedimentary
Basin
Structural setting: Foreland basin setting. Structural setting -
simple
Facies variability: Lateral continuity high and facies
variability homogenous. Vertical variability - moderate.Country:
LT, LV, PL, DK 1. Area extend (km2) 9376 21263 15300 Lognorm 1
Offshore 3206 6413 5000 Lognorm 2 Onshore 6170 14850 10500
Lognorm 1
2. Thickness (gross, m) 9 20 16 Lognorm 1, 22a. Thickness (net,
m) 4,5 10 8 Lognorm 22b. Net/Gross (%) 40 50 45 Lognorm
3. Depth (m) top 1500 2130 1800 1, 2
3. Depth (m) bottom 1500 2150 1825 Lognorm 1, 2
Depth is of the bottom of Late Orodovician (Katian) shale.
4. Density (g/cm3) 2,11 2,76 2,53 Lognorm 1, 2
Grain density values based on measurements. Wt % from QuantaETC
(QXRD) and TOC obtained from RockEval or chemical analysis and
converted into the volume percent (vol.%) of the solid matrix
constituents. Number of measurements - 35. Uncertainty - 50%.
5. TOC (%) 2 7 3,2 Lognorm 1, 2, 4,6
6. Porosity (%) 0,35 14,1 5,7 Lognorm 1,2
7. Maturity (%VR) or graptolite equivalent 0,7 1,1 0,8 Lognorm
1, 2, 3Vitrinite-like particles + graptolites+ bitumines calibrated
to Vitrnite reflectance
8. Reservoir pressure (psi) 1450 1886 1668 2Based on ananlogue
with Lithuanian Silurian Shales
9. Reservoir Temperature (°C) 35,98 91,7 71,1 2
Temperature mesurements at certain depth data. Mean present day
geothermal gradient in Lithuania 25 °C/km. Present day geothermal
gradient in geothermal anomaly in Western Lithuania - 40-45
°C/km.
10. Gas saturation (%)(Sg)No production data available. Polish
Late Ordovician shales would be the best analogue.
11. Oil Saturation (%) So)
No production data available. Test Llandovery oil obtained in 2
wells. Polish Late Ordovician shales would be the best
analogue.
12. Gas generation mgHC/g TOC (Hydrogen index) 86 551 262 1, 2,
6Values based on 32 RockEval and Leco measurements. Uncertainty -
85%
13. Kerogen type II, II-III 1, 2, 6Kerogen type values based on
32 RockEval measurements. Uncertainty - 45%.
14. Sorption capacity VReq. - 1,9 % (mmol/g)
No measurement data. Analogue numbers could be form Furongian
unit of Alum Shale or Polish Silurian shales.
15. Matrix permeability (mDarcy) 1,2
Matrix permeability values based on 70 GRI-derived absolute Kg
determined from pressure decay results. Uncertainity - 70%
16. Adsorbed gas storage capacity (scf/ton)
No measurement data. Analogue numbers could be form Furongian
unit of Alum Shale or Polish Late Ordovician shales.
17. Compressibility factor (z)
No measurement data. Analogue numbers are form Furongian unit of
Alum Shale, or could be from Polish Silurian shales.
18. Bg - Gas formation volume factorNo data available. Polish
Late Ordovician shales would be the best analogue.
19. Langmuir Pressure (pL, psi) 5
No data available. Analogue numbers are form Furongian unit of
Alum Shale, or could be from Polish Late Ordovician shales.
20. Langmuir Volume (nL, scf/ton) 5
No data available. Analogue numbers are form Furongian unit of
Alum Shale, or could be from Polish Late Ordovician shales.
Bulk mineral constituents XRD % Source1,2
Average clay content (%) 49Average quartz-feldspars content (%)
29Average carbonate content (%) 10
TOC values based on 33 RockEval measurements. Uncertainty - 85%.
Porosity valuse based on 10 measurements: 2- GRI-derived absolute
Kg-matrix
Min
eral
ogy
Offshore area comprises maximal area of the Lithuanian Baltic
sea territory where the shale is
REFERENCE LIST : 1 . Investigations of structure and composition
of shaley Lower Paleozoic succession in Lithuanian part of the
Baltic Sedimentary Basin. Report of Lithuanian Geological Survey,
Lazauskiene et al., 2014, 132 pp (in Lithuanian). 2. Lazauskiene,
J., Bitinas, J.,
- Excel sheet with parameters for data distribution. 3.
Petersen, H.I., Schovsbo, N.H., Nielsen, A.T., 2013. Reflectance
measurements of zooclasts and solid bitumen in Lower Palaeozoic
shales, southern Scandinavia: correlation to vitrinite reflectance.
International Journal of Coal Petrology 114, 1–18.
http://www.sciencedirect.com/science/article/pii/S0166516213001080
4. EIA/ARI World Shale Gas and Shale Oil Resource Assessment,
Technically Recoverable Shale Oil and Shale Gas Resources: An
Assessment of 137 Shale Formations in 41 Countries Outside the
United States
http://www.eia.gov/analysis/studies/worldshalegas/pdf/fullreport.pdf
5. Matus Gasparik, Pieter Bertier, Yves Gensterblum, Amin
Ghanizadeh, Bernhard M. Krooss, Ralf Littke, Geological controls on
the methane storage capacity in organic-rich shales - April 2013
6(reds.). 2001. Petroleum Geology of Lithuania and Southeastern
Baltic. Vilnius. 204 p.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 49
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Lemeš1004
Age: Late Jurassic (Kimmeridgian-Tithonian) 1Basin: Dinaric
Mts.
Structural setting: Outer Dinarides, Intraplatform shallow
through 3,4,5,6
Facies variability: Moderate lateral continuety and facies
variability. 3,5,6Country: Croatia 1. Area extend (km2)
Offshore Onshore 36,2 42 39,1 Triangular 3,5,6
2. Thickness (gross, m) 250 450 350 Triangular 1,32a. Thickness
(net, m) 3 70 36,5 Triangular 1,32b. Net/Gross (%) 1,2 15,6 8,4
Triangular 1
3. Depth (m) 0 930 465 Triangular 3
4. Density (g/cm3) 2,6 2,7 2,65 Triangular 2
5. TOC (%) 2 10 6 Triangular 1
6. Porosity (%) 3 5,4 4,2 Triangular 1
7. Maturity (%VR) or graptolite equivalent 0,5 0,7 0,6
Triangular 1
% VR is defined with biomarker thermal maturity and optical
parameters (fluorescence)
8. Reservoir pressure (psi) 0 0 0
Exhumated structure according termal maturity from depth of
approximately 5500-5800 m
9. Reservoir Temperature (°C)
10. Gas saturation (%)(Sg) 0 0 0 Surface
11. Oil Saturation (%) So) 0 0 0 Surface
12. Gas generation mgHC/g TOC (Hydrogen index) 509 602 555,5
1
13. Kerogen type II-S
14. Sorption capacity VReq. - 1,9 % (mmol/g) 0 0 0 Surface
15. Matrix permeability (nDarcy)
These organic rich limestones and calcareous shales (micritic
limestones with clay particles) are classified as
biopelmicrites.
16. Adsorbed gas storage capacity (scf/ton) 0 0 0 Surface
17. Compressibility factor (z) 0 0 0 Surface
18. Bg - Gas formation volume factor 0 0 0 Surface
19. Langmuir Pressure (pL, psi)
20. Langmuir Volume (nL, scf/ton)
Bulk mineral constituents XRD % Source
Average clay content (%) 0
Average quartz-feldspars content (%) 4Average carbonate content
(%) 96 M
iner
alog
y
REFERENCE LIST : 1 .
(2009): Source potential and palynofacies
- 40, 833-845. 2. Application of Artificial
to Mesozoic Source Rocks of Dinarides in Evaluation of
Zagreb, Faculty of Science,
3.
geological map, L -33-141,
tectonics: - -86. 5
– –170.
Evolution of the Adriatic
and depositional dynamics. -
-360.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 50
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Meride fm (Besano fm and Perledo mb)
1005
Age: Ladinian (Triassic)Basin: Lombardy Basin
Structural setting: Passive margin; synrift extentional
tectonic
Facies variability: High lateral and vertical
variability.Country: IT, SW (cf. Grenzbitumenzone) 1. Area extend
(km2) 7743 1, 2
Offshore 0 Onshore 7743 1, 2
2. Thickness (gross, m) 100 400 250 3, 4, 52a. Thickness (net,
m) 10 40 25 3, 4, 52b. Net/Gross (%) 10 10 10 3, 4, 5
3. Depth (m) top 4452 7000 5726 3
Mean depth of top and bottom is referred to the Meride
formation in the Gaggiano 1 well log published in a very
simplified form and is considered also the min. The max depths
can be inferred
from published regional cross sections
3. Depth (m) bottom 4829 7000 5914,5 3
4. Density (g/cm3) No data available.
5. TOC (%) < 1 35 0,9 1, 6
intraformational variability in the Besano fm, mean value from
regional study (1)
6. Porosity (%) No data available.
7. Maturity (%VR) or graptolite equivalent 0,39 2,17 1,28 6,
4
8. Reservoir pressure (psi) No data available.
9. Reservoir Temperature (°C) No data available.
10. Gas saturation (%)(Sg) No data available.
11. Oil Saturation (%) So) No data available.
12. Gas generation mgHC/g TOC (Hydrogen index) 420 800 610 6
values are desumed from the plot reported in (6); min/max
values for kerogen type III are 0-100
13. Kerogen type II-III 6, 7
14. Sorption capacity VReq. - 1,9 % (mmol/g) No data
available.
15. Matrix permeability (mDarcy) No data available.
16. Adsorbed gas storage capacity (scf/ton) No data
available.
17. Compressibility factor (z) No data available.
18. Bg - Gas formation volume factor No data available. 19.
Langmuir Pressure (pL, psi) No data available.
20. Langmuir Volume (nL, scf/ton) No data available. 20.
Langmuir Volume (nL, scf/ton) no data
Bulk mineral constituents XRD % Source
Average clay content (%)Average quartz-feldspars content
(%)Average carbonate content (%) M
iner
alog
y
REFERENCE LIST : 1. Lindquist, S.J. (1999). Petroleum Systems of
the Po Basin Province of Northern Italy and Northern Adriatic Sea:
Porto Garibaldi (Biogenic), Meride/Riva di solto (Thermal), and
Marnoso Arenacea (Thermal). USGS Open-File Report 99-50-M. 2. Riva,
A., Salvatori, T., Cavaliere, R., Ricchiuto, T., and Novelli, L.
(1986). Origin of oils in Po Basin, Northern Italy. Org. Geochem.,
10, 391-400. 3. Bongiorni, D. (1987). The hydrocarbon exploration
in the Mesozoic structural highs of the Po Valley: the example of
Gaggiano. Atti Tic. Sc. Terra, 31, 125-141. 4. Gaetani, M.,
Gnaccolini, M., Poliani, G., Grignani, D., Gorza, M., and
Martellini, L. (1992). An anoxic intraplatform basin in the Middle
Triassic of Lombardy (southern Alps, Italy): anatomy of a
Hydrocarbon source. Riv. It. Paleont. Strat., 97 (3-4), 329-354. 5.
Jadoul, F., and Tintori, A. (2012). The Middle-Late Triassic of
Lombardy (I) and Canton Ticino (CH). In “Pan-European Correlation
of the Triassic - 9th International Field Workshop”. September 1-5,
2012. 6. Katz, B.J., Dittmar, E.I., and Ehret, G.E. (2000).
Geochemical review of carbonate source rocks in Italy. Journal of
Petroleum Geology, vol.23(4), 399-424. 7. Pieri, M., and
Mattavelli, L. (1986). Geologic framework of Italian petroleum
resources. AAPG Bull., 70, 2, 103-130.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 51
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Riva di solto shales (lower lithozone)
1006
Age: NorianBasin: Lombardy Basin
Structural setting: Passive margin; synrift extentional
tectonic
Facies variability: High lateral and vertical variability.
Country: IT5. proposes correlation with
Kossen formation 1. Area extend (km2) 5500 1
Offshore 0 Onshore 5500 1
2. Thickness (gross, m) 200thickness of the lower lithozone
from outcrops2a. Thickness (net, m)2b. Net/Gross (%)
3. Depth (m) top 2764 > 7000 5000 4
Min depth of top and bottom is referred to the whole Riva di
Solto fm in the Gerola 1 well
log; mean and max can be inferred from published regional cross
sections
3. Depth (m) bottom 2947 > 7000 5000 4
4. Density (g/cm3) No data available.
5. TOC (%) 0,5 5 1,3 triangular 2
6. Porosity (%) No data available.
7. Maturity (%VR) or graptolite equivalent 4 3
The literature reported only mean value and the type of
distribution is not indicated
8. Reservoir pressure (psi) No data available.
9. Reservoir Temperature (°C) No data available.
10. Gas saturation (%)(Sg) No data available.
11. Oil Saturation (%) So) No data available.
12. Gas generation mgHC/g TOC (Hydrogen index) 251 2
The literature reported only mean value and the type of
distribution is not indicated
13. Kerogen type II-III 3
14. Sorption capacity VReq. - 1,9 % (mmol/g) No data
available.
15. Matrix permeability (mDarcy) No data available.
16. Adsorbed gas storage capacity (scf/ton) No data
available.
17. Compressibility factor (z) No data available.
18. Bg - Gas formation volume factor No data available. 19.
Langmuir Pressure (pL, psi) No data available.
20. Langmuir Volume (nL, scf/ton) No data available. 20.
Langmuir Volume (nL, scf/ton) no data
Bulk mineral constituents XRD % Source
Average clay content (%)Average quartz-feldspars content
(%)Average carbonate content (%) M
iner
alog
y
REFERENCE LIST : 1. Riva, A., Salvatori, T., Cavaliere, R.,
Ricchiuto, T., and Novelli, L. (1986). Origin of oils in Po Basin,
Northern Italy. Org. Geochem., 10, 391-400. 2, . Lindquist, S.J.
(1999). Petroleum Systems of the Po Basin Province of Northern
Italy and Northern Adriatic Sea: Porto Garibaldi (Biogenic),
Meride/Riva di solto (Thermal), and Marnoso Arenacea (Thermal).
USGS Open-File Report 99-50-M. 3, Stefani, M., and Burchell, M.
(1990). Upper Triassic (Rhaetic) argillaceous sequences in northern
Italy: depositional dynamics and source potential, in Huc, A.Y.,
ed., Deposition of Organic Facies, AAPG Studies in Geology, 30,
American Association of Petroleum Geologists, p. 93-106. 4.
http://unmig.sviluppoeconomico.gov.it/videpi/pozzi/consultabili.asp
5. Veto I., Hetenyi M., Hamor-Vido M., Hufnagel H., Haas J. (2000)
- Anaerobic degradation of organic matter controlled by
productivity variation in a restricted Late Triassic basin. Organic
Geochemistry, 31, 439-452.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 52
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Marne di Bruntino1007
Age: Aptian-AlbianBasin: Lombardy Basin
Structural setting: Passive margin; synrift extentional
tectonic
Facies variability: High lateral and vertical
variability.Country: IT 1. Area extend (km2) 4069 constrained by
well logs
Offshore 0 Onshore 4069
2. Thickness (gross, m) 30 140 80 triangular
thickness from well log stratigraphies (min) and
outcrops (max)
2a. Thickness (net, m) 10 50 10 triangularthickness from well
log
stratigraphies2b. Net/Gross (%) 12,5
3. Depth (m) top 67 4911 2500 triangular 2 Top and bottom min
depth 3. Depth (m) bottom 104 4945 2500 triangular 2
4. Density (g/cm3) No data available.
5. TOC (%) 0,03 15,5 1,01 triangular 1
6. Porosity (%) No data available.
7. Maturity (%VR) or graptolite equivalent No data
available.
8. Reservoir pressure (psi) No data available.
9. Reservoir Temperature (°C) No data available.
10. Gas saturation (%)(Sg) No data available.
11. Oil Saturation (%) So) No data available.
12. Gas generation mgHC/g TOC (Hydrogen index) 0,87 107,6 54
triangular 1
values for samples with at least 1% of organic content
13. Kerogen type II-III 1
14. Sorption capacity VReq. - 1,9 % (mmol/g) No data
available.
15. Matrix permeability (mDarcy) No data available.
16. Adsorbed gas storage capacity (scf/ton) No data
available.
17. Compressibility factor (z) No data available.
18. Bg - Gas formation volume factor No data available. 19.
Langmuir Pressure (pL, psi) No data available.
20. Langmuir Volume (nL, scf/ton) No data available.
Bulk mineral constituents XRD % SourceAverage clay content
(%)
Average quartz-feldspars content (%)
Average carbonate content (%) Min
eral
ogy
REFERENCE LIST : 1. Katz, B.J., Dittmar, E.I., and Ehret, G.E.
(2000). Geochemical review of carbonate source rocks in Italy.
Journal of Petroleum Geology, vol.23(4), 399-424. 2.
http://unmig.sviluppoeconomico.gov.it/videpi/pozzi/consultabili.asp
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 53
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Emma limestones1008
Age: Upper Triassic-Lower JurassicBasin: Emma Basin
Structural setting: Passive margin; synrift extentional
tectonic
Facies variability: High lateral and vertical
variability.Country: IT
1. Area extend (km2) 9365inferred from paleogeographic
regional studies Offshore 5977 Onshore 3388
2. Thickness (gross, m) 50 200 250
thickness from well log stratigraphies and outcrops, net
thickness from (1)2a. Thickness (net, m) 5 24 15 12b. Net/Gross
(%) 6
3. Depth (m) top 4500 >7000 6000
depth info are inferred from deep well logs (not public
available) and published geological cross sections
3. Depth (m) bottom >7000
4. Density (g/cm3) No data available.
5. TOC (%) 0,05 48,3 4,68 triangular 1
6. Porosity (%) No data available.
7. Maturity (%VR) or graptolite equivalent No data
available.
8. Reservoir pressure (psi) No data available.
9. Reservoir Temperature (°C) No data available.
10. Gas saturation (%)(Sg) No data available.
11. Oil Saturation (%) So) No data available.
12. Gas generation mgHC/g TOC (Hydrogen index) 0,04 340,44 47
triangular 1
13. Kerogen type I, II (S) 1,2,3
the variation of the kerogene type is related to the
different
lithotypes (see report)
14. Sorption capacity VReq. - 1,9 % (mmol/g) No data
available.
15. Matrix permeability (mDarcy) No data available.
16. Adsorbed gas storage capacity (scf/ton) No data
available.
17. Compressibility factor (z) No data available.
18. Bg - Gas formation volume factor No data available. 19.
Langmuir Pressure (pL, psi) No data available.
20. Langmuir Volume (nL, scf/ton) No data available.
Bulk mineral constituents XRD % Source MineralogyAverage clay
content (%)
Average quartz-feldspars content (%)Average carbonate content
(%)Average carbonate content (%)
REFERENCE LIST : 1. Katz, B.J., Dittmar, E.I., and Ehret, G.E.
(2000). Geochemical review of carbonate source rocks in Italy.
Journal of Petroleum Geology, vol.23(4), 399-424. 2. Andrè, P., and
Doulcet, A. (1991). Rospo Mare Field – Italy , Apulian Platform,
Adriatic Sea. AAPG Treatise of Petroleum Geology, Atlas of Oil and
Gas Fields A-06, 29-54. 3. Mazzuca, N., Bruni, A., and Jopen, T.
(2015). Exploring the potential of deep targets in the South
Adriatic Sea: insight from 2D basin modeling of the Croatian
offshore. Geologia Croatica, 68/3, 237–246.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 54
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Marne di Monte Serrone1009
Age: Toarcian
Basin: Umbria-Marche Basin
Structural setting: Passive margin; synrift extentional
tectonic
Facies variability: High lateral and vertical
variability.Country: IT
1. Area extend (km2) 20792inferred from paleogeographic
regional studies Offshore 11813 Onshore 8979
2. Thickness (gross, m)2a. Thickness (net, m) 1 24 13 2
thickness from outcrops2b. Net/Gross (%)
3. Depth (m) top 4000 5000 5000
depth info are inferred from deep well logs (not public
available) and seismic profiles 3. Depth (m) bottom
4. Density (g/cm3) No data available.
5. TOC (%) 0,19 2,34 0,95 triangular 1,2
(2) proposed TOC values from 0,5 to 2,7 for black shale
6. Porosity (%) No data available.
7. Maturity (%VR) or graptolite equivalent No data
available.
8. Reservoir pressure (psi) No data available.
9. Reservoir Temperature (°C) No data available.
10. Gas saturation (%)(Sg) No data available.
11. Oil Saturation (%) So) No data available.
12. Gas generation mgHC/g TOC (Hydrogen index) 6,19 1
The literature reported only mean value and the type of
distribution is not indicated
13. Kerogen type II-III 1
14. Sorption capacity VReq. - 1,9 % (mmol/g) No data
available.
15. Matrix permeability (mDarcy) No data available.
16. Adsorbed gas storage capacity (scf/ton) No data
available.
17. Compressibility factor (z) No data available.
18. Bg - Gas formation volume factor No data available. 19.
Langmuir Pressure (pL, psi) No data available.
20. Langmuir Volume (nL, scf/ton) No data available.
Bulk mineral constituents XRD % SourceAverage clay content
(%)Average quartz-feldspars content (%)Average carbonate content
(%)Average carbonate content (%) M
iner
alog
y
REFERENCE LIST : 1. Katz, B.J., Dittmar, E.I., and Ehret, G.E.
(2000). Geochemical review of carbonate source rocks in Italy.
Journal of Petroleum Geology, vol.23(4), 399-424. 2. Parisi, G.,
Ortega Huertas, M., Nocchi, M., Palomo, Monaco, P., Martinez, F.
(1996). Stratigraphy and geochemical anomalies of the early
Toarcian oxygen-poor interval in the Umbria-Marche Apennines
(Italy). GEOBIOS, 29 (4), 469-484.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 55
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Marne a Fucoidi1010
Age: Aptian-Albian
Basin: Umbria-Marche BasinStructural setting: Passive margin;
synrift extentional tectonic
Facies variability: High lateral and vertical
variability.Country: IT
1. Area extend (km2) 20791inferred from paleogeographic
regional studies Offshore 11810 Onshore 8981
2. Thickness (gross, m) 82,53 1max thickness from reference
section (1)
2a. Thickness (net, m) 8 < 42 20 2, 3, 4
max thickness from (4), min thickness from (2), mean from
(3)2b. Net/Gross (%)
3. Depth (m) top 2000 5000 4500
depth info are inferred from deep published maps and geological
cross section
3. Depth (m) bottom
4. Density (g/cm3) No data available.
5. TOC (%) 0,05 25,01 1,82 triangular 2
6. Porosity (%) No data available.
7. Maturity (%VR) or graptolite equivalent No data
available.
8. Reservoir pressure (psi) No data available.
9. Reservoir Temperature (°C) No data available.
10. Gas saturation (%)(Sg) No data available.
11. Oil Saturation (%) So) No data available.
12. Gas generation mgHC/g TOC (Hydrogen index) 0,35 103,1 17,12
triangular 2
13. Kerogen type II-III 2
14. Sorption capacity VReq. - 1,9 % (mmol/g) No data
available.
15. Matrix permeability (mDarcy) No data available.
16. Adsorbed gas storage capacity (scf/ton) No data
available.
17. Compressibility factor (z) No data available.
18. Bg - Gas formation volume factor No data available. 19.
Langmuir Pressure (pL, psi) No data available.
20. Langmuir Volume (nL, scf/ton) No data available.
Bulk mineral constituents XRD % SourceAverage clay content
(%)Average quartz-feldspars content (%)Average carbonate content
(%)Average carbonate content (%) M
iner
alog
y
REFERENCE LIST : 1. Coccioni, R., Jovane, L., Bancalà, G.,
Bucci, C., Fauth, G., Frontalini, F., Janikian, L., Savian, J.,
Paes de Almeida, R., Mathias, G. L., and Ferreira da Trindade, R.
I. (2012). Umbria-Marche Basin, Central Italy: A Reference Section
for the Aptian-Albian Interval at Low Latitudes. Sci. Dril., 13,
42-46. doi:10.5194/sd-13-42-2012. 2. Katz, B.J., Dittmar, E.I., and
Ehret, G.E. (2000). Geochemical review of carbonate source rocks in
Italy. Journal of Petroleum Geology, vol.23(4), 399-424. 3. Arthur,
M., and Silva, I.P. (1982). Development of widespread organic
carbon-rich strata in the Mediterranean Tethys. In: Schlanger, S.
0. and Cita, M. B. (Eds), Nature and Origin of Cretaceous
Carbon-Rich Facies. Academic Press (London), 7-54. 4. Fiet N.
(1998). Les black shales, un outil chronostratigraphique haute
resolution. Exemple del' Albien du bassin de Marches-Ombrie (ltalie
centrale). Bull. Soc. Geol. France, 169, 221-231. 5. Hu X., Jansa
L., Sarti M., 2006. Mid-Cretaceous oceanic red beds in the
Umbria–Marche Basin, central Italy: Constraints on paleoceanography
and paleoclimate. Palaeogeography, Palaeoclimatology, Palaeoecology
233 (3), 163-186 6. Tornaghi, M.E., Premoli Silva, I., and Ripepe,
M., 1989. Lithostratigraphy and planktonic foraminiferal
biostratigraphy of the Aptian-Albian ‘‘Scisti a Fucoidi’’ in the
Piobbico core, Marche, Italy: Background for cyclostratigraphy.
Riv.Ital. Paleont. Strat., 95:223–264.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 56
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Argille Lignitifere
1011
Age: Tortonian-MessinianBasin: Ribolla Basin
Structural setting: extentional tectonic; opening of the
Tyrrhenian basin
Facies variability: High lateral and vertical
variability.Country: IT 1. Area extend (km2) 5564 1
Offshore Onshore 5564 1
2. Thickness (gross, m) 0 80 40 12a. Thickness (net, m) 0 8 8
12b. Net/Gross (%) 0 10 20
3. Depth (m) top 1000 1 3. Depth (m) bottom
4. Density (g/cm3) No data available.
5. TOC (%) 1,38 56,14 20 triangular 1
6. Porosity (%) No data available.
7. Maturity (%VR) or graptolite equivalent 0,825 1,302 1,1 1
8. Reservoir pressure (psi) No data available.
9. Reservoir Temperature (°C) No data available.
10. Gas saturation (%)(Sg)
11. Oil Saturation (%) So) No data available.
12. Gas generation mgHC/g TOC (Hydrogen index)
13. Kerogen type
14. Sorption capacity VReq. - 1,9 % (mmol/g) No data
available.
15. Matrix permeability (mDarcy) No data available.
16. Adsorbed gas storage capacity (scf/ton) No data
available.
17. Compressibility factor (z) No data available.
18. Bg - Gas formation volume factor No data available.
19. Langmuir Pressure (pL, psi) No data available.
20. Langmuir Volume (nL, scf/ton) No data available.
Bulk mineral constituents XRD % Source
Average clay content (%)Average quartz-feldspars content (%)
Average carbonate content (%)
Min
eral
ogy
REFERENCE LIST : 1. Bencini, R., Bianchi, E., De Mattia, R.,
Martinuzzi, A., Rodorigo, S. and Vico, G. (2012). Unconventional
Gas in Italy: the Ribolla Basin. AAPG, Search and Discovery Article
#80203.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 57
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Noto Shale
1012
Age: RhaetianBasin: Ragusa
Structural setting: foreland
Facies variability: mediumCountry: Italy 1. Area extend (km2)
5090
Offshore 1190 Onshore 3900
2. Thickness (gross, m) 250 300 275 triangular 2, 42a. Thickness
(net, m) 20 42b. Net/Gross (%) 7
3. Depth (m) 2800 3100 2900 triangular 2,3,4
4. Density (g/cm3)
5. TOC (%) 0,2 10 4 triangular 1,2
6. Porosity (%)
7. Maturity (%VR) or graptolite equivalent
8. Reservoir pressure (psi)
9. Reservoir Temperature (°C)
10. Gas saturation (%)(Sg)
11. Oil Saturation (%) So)
12. Gas generation mgHC/g TOC (Hydrogen index) 300 550 412 5
13. Kerogen type II 1,2
14. Sorption capacity VReq. - 1,9 % (mmol/g)
15. Matrix permeability (nDarcy)
16. Adsorbed gas storage capacity (scf/ton)
17. Compressibility factor (z)
18. Bg - Gas formation volume factor
19. Langmuir Pressure (pL, psi)
20. Langmuir Volume (nL, scf/ton)
Bulk mineral constituents XRD % Source
Average clay content (%) 71 2Average quartz-feldspars content
(%) 23
Average carbonate content (%) 6
Min
eral
ogy
REFERENCE LIST : 1 . Pieri, M., and Mattavelli, L. (1986).
Geologic framework of Italian petroleum resources. AAPG Bull., 70,
2, 103-130 2. Brosse, E., Loreau, J.P., Huc, A.Y., Frixa, A.,
Martellini, L., Riva, A., 1988. The organic matter of interlayered
carbonates and clays sediments — Trias/Lias, Sicily. Org. Geochem.
13, 433–443 3. Frixa, A., Bertamoni, M., Catrullo, D., Trinicianti,
E., Miuccio, G., 2000. Late Norian —Hettangian palaeogeography in
the area between wells Noto 1 and Polpo 1 (S-E Sicily). Mem. Soc.
Geol. Ital. 55, 279–284. 4.
http://unmig.sviluppoeconomico.gov.it/videpi/pozzi/consultabili.asp
5. Novelli, L., Welte, D.H., Mattavelli, L., Yalçin, M.N., Cinelli,
D., and Schmitt, K.J. (1988). Hydrocarbon generation in southern
Sicily. A three dimensional computer aided basin modeling study.
Organic Geochemistry, 13 (1-3), 153–164.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 58
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Streppenosa Shale
1013
Age: Norian - Rhaetian - HettangianBasin: Ragusa
Structural setting: foreland
Facies variability: mediumCountry: Italy 1. Area extend
(km2)
Offshore 8535 Onshore 4065
2. Thickness (gross, m) 20 3000 1510 1,2,3,42a. Thickness (net,
m)
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Alum Shale Formation
1014
Age: M. Cambrian-E. OrdovicianBasin: Baltic Basin
Structural setting: gently dipping succession to the
south-south-east
Northeast marings of the Baltic Basin also commonly known as
the baltic Syneclise
Facies variability: Inner and outer shelf black shale with
anthracontie and limestone interbeds
Country: Sweden 1. Area extend (km2)
Offshore 10121 Onshore 106
2. Thickness (gross, m) 20 35 25 1Only south Öland, where
the
thickness exceeds 20 m2a. Thickness (net, m) 15 25 202b.
Net/Gross (%) 75 83 80
3. Depth (m) 0 800 300 1, 3
Outcrops on south Öland, deepest in offshore areas,
estimated mean. 728-758,5 m in the Yoldia-1 well
4. Density (g/cm3) n.d. n.d. n.d.
5. TOC (%) 7 14 11 normal 4
6. Porosity (%) n.d. n.d. n.d.
7. Maturity (%VR) or graptolite equivalent 0,4 0,77 0,61 2
8. Reservoir pressure (psi) 14,5 1160 435Hydrostatic pressure
calculated
from depth data (3)
9. Reservoir Temperature (°C) 8* 35** 15* mean annual surface
grouns
temperature**Based on BHT in Yoldia-1
10. Gas saturation (%)(Sg) n.d. n.d. n.d.
11. Oil Saturation (%) So) n.d. n.d. n.d.
12. Gas generation mgHC/g TOC (Hydrogen index) 282 458 358
5,6
13. Kerogen type II II II 2,5
14. Sorption capacity VReq. - 1,9 % (mmol/g) n.d. n.d. n.d.
15. Matrix permeability (nDarcy) n.d. n.d. n.d.
16. Adsorbed gas storage capacity (scf/ton) n.d. n.d. n.d.
17. Compressibility factor (z) n.d. n.d. n.d.
18. Bg - Gas formation volume factor n.d. n.d. n.d.
19. Langmuir Pressure (pL, psi) n.d. n.d. n.d.
20. Langmuir Volume (nL, scf/ton) n.d. n.d. n.d.
Bulk mineral constituents XRD % Source
Average clay content (%) n.d.Average quartz-feldspars content
(%) n.d.Average carbonate content (%) n.d. M
iner
alog
y
REFERENCE LIST : 1 . Dahlman, B., 1977: Öands Alunskiffer.
Sveriges geologiska undersökning rapport DOCNO 31188. 2. Schovsbo,
N., 2002: Uranium enrichment shorewards in balck shales: A case
study from the Scandinavian Alum Shale. GFF 124, 107-115. 3.
Completion report Yodia-1, OPAB. 1988. 4.Andersson, A., Dahlman,
B., Gee, D.G. & Snäll, S., 1985: The Scandinavian Alum Shales.
Sveriges geologiska undersökning Ca 56, 50 pp. 5. Wrang, P., 1984:
Organic Geochemical Investiation of Selected Palaeozoic Samples
from Sweden. GEUS report 43. 6.Pedersen, J.H., Karlsen, D.A., Lie,
J.E., Brunstad, H. & di Primio, R., 2006: Maturity and
source-rock potential of Palaeozoic sediments in the NE European
Norhtern Permian Basin. Petroleum Geoscience 12, 13-28.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 60
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Alum Shale Formation 1015Age: M. Cambrian-E.
OrdovicianBasin: Sorgenfrei Tornquist Zone
Structural setting: complex strucural setting with several local
and regional fault bounded rock blocks being uplifted during L.
Cretaceous inversion 1,2
Facies variability: Outer shelf black shale with some limestone
and antraconite interbedsCountry: Sweden 1. Area extend (km2)
2835
Offshore 450 Onshore 2385
2. Thickness (gross, m) 61 98,5 80 2, 3, 42a. Thickness (net, m)
762b. Net/Gross (%) 95 Assessed
3. Depth (m) 0 1000* 800
Assessed maximum depth. Mean depth is representative for the
Colonus Shale Trough
4. Density (g/cm3) 2,33 2,81 2,54 4
Density values taken from Shell exploration wells (depth range
685-950 m)
5. TOC (%) 0,5 13,7 7,5 normal 4TOC also from Shell deep
exploration wells
6. Porosity (%) 1 10,2 6,1 4
Dry helium porosity % of bulk volume. Data from Shell deep
exploration wells
7. Maturity (%VR) or graptolite equivalent 2,12 2,5 2,29 4
1,8 4,91 2,65 5,68. Reservoir pressure (psi)
9. Reservoir Temperature (°C) 10* 33 28 4
* average surface annual temp. Max temp calculated using a
gradient of 3.3 deg/100 m, based on temp data from logs in deep
wells
10. Gas saturation (%)(Sg) 7,5 53,2 20,6 4 % of pore volume
11. Oil Saturation (%) So) 0 27,9 3,56 4 % of pore volume
12. Gas generation mgHC/g TOC (Hydrogen index)
13. Kerogen type II II II
14. Sorption capacity VReq. - 1,9 % (mmol/g)
15. Matrix permeability (nDarcy) n.d. n.d. n.d.
16. Adsorbed gas storage capacity (scf/ton) n.d. n.d. n.d.
17. Compressibility factor (z) n.d. n.d. n.d.
18. Bg - Gas formation volume factor n.d. n.d. n.d.
19. Langmuir Pressure (pL, psi) n.d. n.d. n.d.
20. Langmuir Volume (nL, scf/ton) n.d. n.d. n.d.
Bulk mineral constituents XRD % Source
Average clay content (%) 48 4Average quartz-feldspars content
(%) 33Average carbonate content (%) 7,5 M
iner
alog
y
Central Scania including both deep occurrences of Alums Shale as
well as shallow occurrences on the Linderödsåsen ridge flanking the
Colonus Shale Trough to the NE
REFERENCE LIST : 1. Calner, M., Erlström, M., Eriksson, M.,
Ahlberg, P. & Lehnert, O., 2013: Regional geology of the Skåne
province, Sweden. In M. Calner, P. Ahlberg, O. Lehnert & M.
Erlström (eds.) The Lower Palaeozoic of southern Sweden and the
Oslo Region, Norway. Filed Guide for the 3rd Annual Meeting of the
IGCP project 591. SGU, Rapporter och meddelanden 133, 37 39. 2 .
Erlström, M., Sivhed, U. ,Wikman, H. &Kornfält, K.-A., 2004:
Beskrivning till berggrundskartorna 2D Tomelilla NV, NO, SV, SO, 2E
Simrishamn NV, SV, 1D Ystad NV, NO och 1E Örnahusen NV. Sveriges
geologiska undersökning, Af 212-214. 141 s. 3. Sivhed, U. ,Wikman,
H. & Erlström, M., 1999: Beskrivning till berggrundskartorna 1C
Trelleborg NV och NO samt 2C Malmö SV, SO, NV och NO. Sveriges
geologiska undersökning, Af 191-196, 198. 143 s 4. Shell
exploration. Documentation from exploration activites in Skåne
2008-2011. Sveriges geologiska undersökning. Dnr 212-924-2011. 5.
Buchardt, B. & Cederberg, T. 1987: Stabil isotop geokemi i
moderbjergarter, olie og gas i Danmark. Afsluttende rapport, EFP-83
projekt, Kobenhavn, 33 p. (In Danish) 6. Buchardt, B., Nielsen,
A.T., Schovsbo, N. & Wilken, U. G., 1994: Source rock potential
and thermal maturity of Lower Paleozoic black shales in
Baltoscandia. PREWSOR-Project Group, Geological Institute,
University of Copenhagen, Copenhagen, 58 pp.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 61
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Alum Shale Formation1016
Age: M. Cambrian-E. Ordovician
Basin: Danish Basin, Höllviken Halfgraben
Structural setting: Foreland basin, affected by Variscan and
Alpine wrench faulting coupled with extension 1
Facies variability: Outer shelf black shale with some limestone
and antraconite interbedsCountry: Sweden 1. Area extend (km2)
Offshore 1106 Onshore 504
2. Thickness (gross, m) 35 44 40 22a. Thickness (net, m) 35 44
402b. Net/Gross (%) 100
3. Depth (m) 1370 2500 2300 2
4. Density (g/cm3)
5. TOC (%)
6. Porosity (%)
7. Maturity (%VR) or graptolite equivalent 2,9 3,2* 3 3 From
Håslöv-1
8. Reservoir pressure (psi)
9. Reservoir Temperature (°C)
10. Gas saturation (%)(Sg)
11. Oil Saturation (%) So)
12. Gas generation mgHC/g TOC (Hydrogen index)
13. Kerogen type
14. Sorption capacity VReq. - 1,9 % (mmol/g)
15. Matrix permeability (nDarcy)
16. Adsorbed gas storage capacity (scf/ton)
17. Compressibility factor (z)
18. Bg - Gas formation volume factor
19. Langmuir Pressure (pL, psi)
20. Langmuir Volume (nL, scf/ton)
Bulk mineral constituents XRD % Source
Average clay content (%)Average quartz-feldspars content
(%)Average carbonate content (%) M
iner
alog
y
REFERENCE LIST : 1. Calner, M., Erlström, M., Eriksson, M.,
Ahlberg, P. & Lehnert, O., 2013: Regional geology of the Skåne
province, Sweden. In M. Calner, P. Ahlberg, O. Lehnert & M.
Erlström (eds.) The Lower Palaeozoic of southern Sweden and the
Oslo Region, Norway. Filed Guide for the 3rd Annual Meeting of the
IGCP project 591. SGU, Rapporter och meddelanden 133, 37 39. 2 .
Sivhed, U. ,Wikman, H. & Erlström, M., 1999: Beskrivning till
berggrundskartorna 1C Trelleborg NV och NO samt 2C Malmö SV, SO, NV
och NO. Sveriges geologiska undersökning, Af 191-196, 198. 143 s.
3. Buchardt, B., Nilesen, A.T. & Schovsbo, N.H., 1997: Alun
Skiferen i Skandinavien. Geologisk Tidskrift 3, 1-30.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 62
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Alum Shale Formation1017
Age: M. Cambrian-E. OrdovicianBasin: Fennoscandian Shield 1, 2,
3 Västergötland, Östergötland
Structural setting: Shield platform
Facies variability: Inner black shale with limestone and
antraconite interbedsCountry: Sweden 1. Area extend (km2)
Offshore Onshore 1497
2. Thickness (gross, m) 11 24 20 9
22-24 m in Västergötland, 11-20 in Östergötland, 13-19 m in
Närke2a. Thickness (net, m) 9 19 162b. Net/Gross (%) 0,8
Assessed
3. Depth (m) 0 150 30
0-170m in Östergötland, 0-30m in Närke, 0-150 m in Västergötland
(ref 9)
4. Density (g/cm3)
5. TOC (%) 0,5 22 11 normal 3, 4, 5, 6
6. Porosity (%)
7. Maturity (%VR) or graptolite equivalent 0.43 6,34 0,6 log
normal 3, 4, 5, 6, 7, 8
High values related to thermal impact from Permian dolerite
dykes(sills) in Västergötland(
Ref 9)
8. Reservoir pressure (psi) n.d. n.d. n.d.
9. Reservoir Temperature (°C) n.d. n.d. n.d.
10. Gas saturation (%)(Sg) n.d. n.d. n.d.
Data might be availble from Gripen Gas exploration in
östergötland
11. Oil Saturation (%) So) n.d. n.d. n.d.
12. Gas generation mgHC/g TOC (Hydrogen index) 332 1000 513
5,6
13. Kerogen type II
14. Sorption capacity VReq. - 1,9 % (mmol/g) n.d. n.d. n.d.
15. Matrix permeability (nDarcy) n.d. n.d. n.d.
16. Adsorbed gas storage capacity (scf/ton) n.d. n.d. n.d.
17. Compressibility factor (z) n.d. n.d. n.d.
18. Bg - Gas formation volume factor n.d. n.d. n.d.
19. Langmuir Pressure (pL, psi) n.d. n.d. n.d.
20. Langmuir Volume (nL, scf/ton) n.d. n.d. n.d.
Bulk mineral constituents XRD % Source
Average clay content (%) 40 9Average quartz-feldspars content
(%) 35
Average carbonate content (%) 1 Min
eral
ogy
REFERENCE LIST : 1. Calner, M., Erlström, M., Eriksson, M.,
Ahlberg, P. & Lehnert, O., 2013: The Lower Palaeozoic of
southern Sweden and the Oslo Region, Norway. Filed Guide for the
3rd Annual Meeting of the IGCP project 591. SGU, Rapporter och
meddelanden 133, 96 pp. 2. Andersson, A., Dahlman, B., Gee, D.G.
& Snäll, S., 1985: The Scandinavian Alum Shales. Sveriges
geologiska undersökning Ca 56, 50 pp. 3. Schovsbo, N., 2002:
Uranium enrichment shorewards in balck shales: A case study from
the Scandinavian Alum Shale. GFF 124, 107-115. 4. Dahl, J.,
Hallberg, R. & Kaplan, I.R., 1988: The effects of radioactive
decay of uranium on elemental and isotope ratios of Alum Shale
kerogen. Applied Geochemistry 3, 583-589. 5. Pedersen, J.H.,
Karlsen, D.A., Lie, J.E., Brunstad, H. & di Primio, R., 2006:
Maturity and source-rock potential of Palaeozoic sediments in the
NE European Norhtern Permian Basin. Petroleum Geoscience 12, 13-28.
6 . Krüger, M., van Berk, W., Arning, E.T., Jimenéz, N., Schovsbo,
N.H., Straaten, N. & Schultz, H.M., , 2014: The biogenic
methane potential of European gas shale analogues: Results from
incubation experiments and thermodynamic modelling. International
Journal of Coal Geology 136, 59-74. 7. Thomsen, E., 1984: A
coalification study of Lower Palaeozoic deposits from Denmark and
Sweden. GEUS report 36. 8. Buchardt, B. & Lewan, M.D., 1990:
Reflectance of Vitrinite-Like Macerals as a Thermal Maturity Index
for Cambrian-Orodovician Alum Shale, Southern Scandinavia. The
American Association of Petroleum Geologists Bulletin 74, 394-406.
9. Hessland, I. & Armands, G., 1978: Alunskiffer. Utredning
från Statens industriverk, SIND PM 1978:3, 1-94. 10. Armands, G.,
1972: Geochemical studies of uranium, molybdenum and vanadium in
Swedish alum shale. Stockholm Contributions in Geology 27,
1-148.
Appendix B Shale layer characteristics from NGS Overview of
shale layers characteristics in Europe
Source: Schovsbo, N.H., Anthonsen, K.L., Pedersen, C.B.,
Tougaard, L., 2017. Overview of shale layers characteristics in
Europe relevant for assessment of unconventional resources.
Delivery T6b of the EUOGA study (EU Unconventional Oil and Gas
Assessment) commissioned by JRC-IET to GEUS.
Page 63
-
EUOGA Critical Parameter (Screening criteria) Min Max Mean
Distribution
Source (Ref.list) Comments
Shale Name: Mikulov Marl
1018
Age: Malmian (Upper Jurassic)Basin: Vienna Basin
Structural setting
Facies variability: uniform MarlsCountry: A, CZ 1. Area extend
(km2)
Offshore Onshore 729
2. Thickness (gross, m)2a. Thickness (net, m) 150 900 525
10.
2b. Net/Gross (%)(Cross-Sections & Wells see Ref.
10)
3. Depth (m) 4000 7000 5500 10.(Cross-Sections & Wells see
Ref.
10)4. Density (g/cm3) 2,24 6.
5. TOC (%) 1,5 10 2 1.,3.,4.
6. Porosity (%) 0 9 5 5.
7. Maturity (%VR) or graptolite equivalent 0,7 2,2 1,2 2.,
4.
1,2% at "mean depth" of 5500m
8. Reservoir pressure (psi) 5800 22000 13900 8.
9. Reservoir Temperature (°C) 70 230 150 5.,7., 8.
10. Gas saturation (%)(Sg) no published data
11. Oil Saturation (%) So) no published data
12. Gas generation mgHC/g TOC (Hydrogen index) 150 400 300
1.
13. Kerogen type III II II-III 1.
14. Sorption capacity VReq. - 1,9 % (mmol/g) no published
data