Overview of shale layers characteristics in Europe relevant for … · 2017. 9. 13. · Overview of shale layers characteristics in Europe Delivery T6b. Appendix Volume A-D February

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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



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.



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



CP index

1001

1002

1003

1004100510061007100810091010

101110121013

10141015

1016101710181019102020211022102310241025102610271028102910301031103210331034103510381039104010411042

104310451046104710481049105010511052

1053

10541055

1056

Basin Structural setting

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



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



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



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




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









Europe 6490 4489 5200Europe 9773 4668 7439Europe 4662 12703 3755Europe 6025 4513 3446North America 48692 0 48692North America



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



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



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



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



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



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



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


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 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



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


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.




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)


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.


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.




Page 49



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)


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.




Page 50



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


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.




Page 51



Shale Name: Riva di solto shales (lower lithozone)

1006

Age: NorianBasin: Lombardy Basin


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


5. TOC (%) 0,5 5 1,3 triangular 2


7. Maturity (%VR) or graptolite equivalent 4 3

The literature reported only mean value and the type of distribution is not indicated





12. Gas generation mgHC/g TOC (Hydrogen index) 251 2


13. Kerogen type II-III 3






20. Langmuir Volume (nL, scf/ton) No data available. 20. Langmuir Volume (nL, scf/ton) no data



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.




Page 52



Shale Name: Marne di Bruntino1007

Age: Aptian-AlbianBasin: Lombardy Basin


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


5. TOC (%) 0,03 15,5 1,01 triangular 1


7. Maturity (%VR) or graptolite equivalent 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







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




Page 53



Shale Name: Emma limestones1008

Age: Upper Triassic-Lower JurassicBasin: Emma Basin


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


5. TOC (%) 0,05 48,3 4,68 triangular 1







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)







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.




Page 54



Shale Name: Marne di Monte Serrone1009

Age: Toarcian

Basin: Umbria-Marche Basin





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


5. TOC (%) 0,19 2,34 0,95 triangular 1,2

(2) proposed TOC values from 0,5 to 2,7 for black shale







12. Gas generation mgHC/g TOC (Hydrogen index) 6,19 1









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.




Page 55



Shale Name: Marne a Fucoidi1010

Age: Aptian-Albian

Basin: Umbria-Marche BasinStructural setting: Passive margin; synrift extentional tectonic




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


5. TOC (%) 0,05 25,01 1,82 triangular 2







12. Gas generation mgHC/g TOC (Hydrogen index) 0,35 103,1 17,12 triangular 2








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.




Page 56



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


5. TOC (%) 1,38 56,14 20 triangular 1


7. Maturity (%VR) or graptolite equivalent 0,825 1,302 1,1 1



10. Gas saturation (%)(Sg)


12. Gas generation mgHC/g TOC (Hydrogen index)

13. Kerogen type





18. Bg - Gas formation volume factor No data available.

19. Langmuir Pressure (pL, psi) No data available.



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.




Page 57



Shale Name: Noto Shale

1012

Age: RhaetianBasin: Ragusa

Structural setting: foreland

Facies variability: mediumCountry: Italy 1. Area extend (km2) 5090


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)




12. Gas generation mgHC/g TOC (Hydrogen index) 300 550 412 5

13. Kerogen type II 1,2





18. Bg - Gas formation volume factor




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.




Page 58



Shale Name: Streppenosa Shale

1013

Age: Norian - Rhaetian - HettangianBasin: Ragusa

Structural setting: foreland

Facies variability: mediumCountry: Italy 1. Area extend (km2)


2. Thickness (gross, m) 20 3000 1510 1,2,3,42a. Thickness (net, m)



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)


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.


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.


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.




Page 60



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


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


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


13. Kerogen type II II II









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.




Page 61



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)


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)





13. Kerogen type





18. Bg - Gas formation volume factor





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.




Page 62



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.








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.




Page 63



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

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