Presentation on theme: "NPD’s play models and undiscovered resources in the Barents Sea."— Presentation transcript:
NPD’s play models and undiscovered resources in the Barents Sea
Table of contents Major structural elements Exploration history and the current situation in the Barents Sea Exploration results since 2006 NPD’s database Play models of the Barents sea Prognoses and resource estimates Summary 05/05/20152
The Barents Sea area The Barents Sea north of 74°30’ is characterized as little known area The Barents Sea south of 74°30’, apart from the Hammerfest Basin, is characterized as moderately known area The Hammerfest Basin is characterized as a well known area Little known area Moderately known area Well known area Unknown area Area of overlapping claims (disputed area)
05/05/20155 History and current situation Opened for exploration drilling in 1980 (5 th concession round) First well drilled in 1980 (7119/12-1) First discovery Askeladd (7120/8-1) in 1981 First commercial oil discovery was Goliat (7122/7-1) in 2000 81 exploration wells have so far been drilled in the Norwegian Barents Sea. About half in the Hammerfest Basin One field in production (Snøhvit) and one is under development (Goliat) Currently 42 active production licenses.
05/05/20156 18 exploration wells drilled 7 new discoveries 5 successful appraisal wells 6 dry wells Almost 70 % discovery rate Proven resources since 2006 Oil approx. 20 M Sm 3 Gas approx 100 G Sm 3 Two play models are confirmed APA 2007, APA 2008 & 20 th concession round resulted in 18 new production licenses. What has happened since the awards of the 19 th concession round? 7122/7-3 Kobbe Goliat (Oil) 7122/7-4S Klappmys Goliat (Oil) 7125/4-1 Nucula (Oil & Gas) 7222/6-1S Obesum (Oil) 7222/11-1 Caurus (Gas) 7224/6-1 Arenaria (Gass) 7226/2-1 Ververis (25 gass) 7120/6-2S (Snøhvit) 7122/6-2 (Tornerose) 7122/7-5A (West Goliat) 7125/4-2 (Nucula) 7223/5-1 (Obesum) 7120/8-4 (wild cat, Askeladd Beta) 7122/7-5 (wild cat, West Goliat structure) 7123/4-1S (appraisal, Snøhvit) 7123/4-1A (appraisal, Snøhvit) 7227/11-1S (wild cat, Uranus) 7227/11-1A (wild cat, Uranus)
Database 05/05/20157 Medium to good seismic coverage south of Bjørnøya Good well density in the Hammerfest basin Relatively low density in the surrounding areas NPD’s prospect database consists of over 1000 prospects, a fourth of these in the Barents sea.
Play models 05/05/20158 LevelReservoir rock Confirmed play models Unconfirmed play models Total Paleogene to neogen Siliclastic22 Upper Jurassic to lower Cretaceous Siliclastic11 JurassicSiliclastic33 Triassic Siliclastic 44 Upper Carboniferous to permian Carbonates and some siliclastic189 Devonian to lower carboniferous Siliclastic and some carbonate44 Total81523 23 play models in total, 8 confirmed, 15 unconfirmed
NPD’s play model definitions A play is defined as a stratigraphically delimited area where a specific set of geological factors must be present so that petroleum may be provable in commercial quantities. Undiscovered resources in a play include both mapped (prospects) and unmapped (leads and potential prospects) resources.
10 Elements Source Rock Migration Route Reservoir Rock Trap Seal Rock Process Generation Migration Accumulation Preservation NPD’s play model definitions Reservoir Mature source rock Valid trap and seal Play
Distribution of Barents Sea play models Carboniferous & Permian 11 PlayAgeArea BCL-3 Visean - Serpukhovian Finnmark Platform BCL-4 Tournaisian- SerpukhovianLoppa High PlayAgeArea BPM, PU-4 Sakmarian- Artinskian/ Kazanian Finnmark Platform BPM, PU-5 Ufimian/ (Kungurian)- Kazanian Loppa High BPU-4 Finnmark Platform PlayAgeArea BCU, PP-4 Serpukovian/ Bashkirian - Tatarian C. and w. part of the Finnmark Platform BCU, PP-5Loppa High BCU, PL-3 Moscovian - Early Sakmarian Finnmark Platform BCU, PL-4Loppa High
Attractive elements Carboniferous/Permian Source rocks mainly coal, of Early Carboniferous age have been proven Reservoir is proven in the western part of the Loppa High in well 7120/2-1 Many plays not confirmed Well 7120/2-1 penetrated karstified limestone sequence with good oil shows BPU-4: Model confirmed by discovery 7128/4-1 Depositional environment Carboniferous Fluvial and alluvial Carboniferous/Permian Syn- and post tectonic infill in active rift basins in a shallow marine setting, on tidal flats and in shallow evaporite basins Permian Marine, temperate to cold water Reservoir rock Carboniferous Sandstone & conglomerate Permian Karstified limestone, limestone, dolomite, spiculites /chert and silicified limestone Trap Carboniferous Both structural and stratigraphic Permian Mainly stratigraphic Source rock Carboniferous Late Devonian to Early Carboniferous (Hoelbreen Member Equivalent) and U. Carboniferous/Lower Permian shales Permian Early Carboniferous and Late Carboniferous/Early Permian shales Critical factors: Carboniferous Non-preservation and leakage of hydrocarbons owing to tilting, reactivation of faults and Tertiary/Quaternary uplift and erosion Presence of mature source rock Permian Non-preservation and leakage of hydrocarbons owing to tilting, reactivation of faults and Tertiary/Quaternary uplift and erosion Presence and quality of reservoir Distribution of Barents Sea play models Carboniferous, Permian 12 Barents Sea Margin Loppa High Nordkapp Basin H B Finnmark Plattform Gardar- banken High Bjarmeland Plattform Edgeøya Plattform Sentralbanken High Olga Basin
Distribution of Barents Sea play models Triassic 13 PlayAgeArea BRL, RM-4 Scythian - Anisian Bjarmeland- and Finnmark Platform, eastern Hammerfest Basin, Nordkapp Basin BRL, RM-5 Eastern part of the Loppa High, Bjarmeland Platform, Mercurius High, Maud Basin BRU-1 Ladinian - Norian Bjarmeland Platform, northeastern part of the Finnmark Platform, eastern part of the Hammerfest Basin, Nordkapp Basin BRU-2 Bjørnøya Basin, Fingerdjupet Sub-basin, Bjarmeland Platform, Maud Basin, Mercurius High, Loppa High, Veslemøy High, Bjørnøyrenna Fault Complex
Critical factors The areas has been affected by Late Tertiary/Quaternary uplift and inversion, this could have trigged possible leakage of prospective hydrocarbon accumulations Lateral extent and quality of reservoir rock Group/Formation BRL, RM-4 and 5: Sassendalen Group with the Havert-, Klappmyss- and Kobbe Formation BRU-1 and 2: Kapp Toscana Group with the Snadd Formation Reservoir rock Sandstone Attractive features BRL, RM-4, BRU-1: Confirmed by several gas and gas/oil discoveries The discovery 7226/11-1 confirmed source rock of Upper Permian age The discovery 7228/7-1 A indicates source rock of Carnian age in the eastern Hammerfest Basin and in the Nordkapp Basin Stratigraphic and structural traps are identified BRL, RM-5: Source rock confirmed by exploration- and shallow wells penetrating the Klappmyss- and Kobbe Formation BRU-1 and -2: Moderate to good reservoir quality Along the Western Fault Margin and the Loppa High source rocks of Jurassic and Cretaceous age may be present Depositional environment Fluvial, deltaic, coastal plain and shallow marine Source rock Upper Devonian- Lower Carboniferous shales, Lower Carboniferous coals, Upper Permian shales and Upper Triassic delta plain facies Trap Stratigraphic, rotated fault blocks and halokinetic Distribution of Barents Sea play models Triassic 05/05/201514 Barents Sea Margin Loppa High Nordkapp Basin H B Finnmark Plattform Gardar- banken High Bjarmeland Plattform Edgeøya Plattform Olga Basin Sentralbanken High
Distribution of Barents Sea play models Lower – middle Jurassic 15 PlayAgeArea BJL, JM-5 Rhaetian - Bajocian Hammerfest Basin BJL, JM-6 Hettangian - Bajocian Bjørnøya Basin, Bjørnøyrenna Fault Complex, Ringvassøy- Loppa Fault Complex, Veslemøy High, Polhem Sub-Platform BJL, JM-7 Eastern part of the Finnmark Platform, Nordkapp Basin, Southern part of the Bjarmeland Platform, Maud Basin, Fingerdjupet Sub Basin
Distribution of Barents Sea play models Jurassic 05/05/201516 Barents Sea Margin Loppa High H B Finnmark Plattform Gardar- banken High Bjarmeland Plattform Edgeøya Plattform Olga Basin Sentralbanken High Nordkapp Basin Depositional environment Fluvial, deltaic and shallow marine Group/Formation Kapp Toscana Group with the Tubåen-, Nordmela- and Stø Formations Reservoir rock Sandstone Source rock BJL, JM-5 and 6: Upper Jurassic shale (Hekkingen Formation). Older source rocks may be present for BJL, JM-6 BJL JM-7: Mainly Early to Mid Triassic shale (Steinkobbe Formation) Shales of Ladinian and Carnian age (in the Nordkapp basin: only Carnian) Trap Rotated fault blocks and horsts BJL, JM-7 in the Nordkapp Basin: Stratigraphic traps related to salt diapers. Rotated fault blocks may also occur Critical factors Non-preservation and leakage of hydrocarbons owing to tilting, reactivation of faults and Tertiary/Quaternary uplift and erosion, especially for shallow and/or truncated structures. The thickness of the Nordmela- and Stø Formation decreases towards northeast Cap rock with sufficient sealing capacity BJL, JM-7: Source rocks in the Steinkobbe Formation deposited only in the Fingerdjupet Sub Basin, Maud Basin and the western part of the Bjarmeland Platform Attractive features Tubåen- and Stø Formation have good reservoir quality, except in the deepest basins Tubåen Formation dominates towards the northeast BJL, JM-5: Confirmed by the discoveries 7121/4-1 Snøhvit, 7120/8-1 Askeladd and 7120/9-1 Albatross, all included in the Snøhvit field, and the oil discovery 7122/7-1 Goliat Efficient and mature source rocks proven in the Hammerfest Basin Cap rocks with sealing capacity confirmed in the Nordkapp Basin
Distribution of Barents Sea play models Upper Jurassic – Lower Cretaceous 17 PlayAgeArea BJU, KL-3 Kimmeridgian- Albian Hammerfest Basin, terraces along Western Fault Margin
Trap Stratigraphic and occasionally structural Critical factors Long-distance migration The areas have been affected by Late Tertiary/Quaternary uplift which probably have affected the storage of originally accumulated petroleum in the Hammerfest Basin and the terraces of the Western Fault Margin Depositional environment Shallow and deep marine Group/Formation Adventdalen Group with the Hekkingen-, Knurr- Kolje- and Kolmule Formations. Reservoir rock Sandstone Attractive features Knurr and Kolje Formation: Good reservoir quality in most of the exploration area In the northern part of the Hammerfest Basin significant volumes of sands are proven in deep marine fans The wells 7120/1-2 and 7120/2-2 have been production tested and the tests indicate mobile hydrocarbons Source rock Late Jurassic shale of the Hekkingen Formation Distribution of Barents Sea play models Upper Jurassic – Lower Cretaceous 05/05/201518 Barents Sea Margin Loppa High Nordkapp Basin H B Finnmark Plattform Gardar- banken High Olga Basin Bjarmeland Plattform Edgeøya Plattform Sentralbanken High
Distribution of Barents Sea play models Paleogene 19 PlayAgeArea BTT-5 Late Paleocene- Oligocene Hornsund Fault Complex, Vestbakken Vulcanic Province, Sørvestnaget Basin, Tromsø Basin, Harstad Basin, western part of the Bjørnøya Basin
Group/Formation Sotbakken Group with the Torsk Formation Reservoir rock Sandstone Trap Rotated fault blocks, domes- and horsts, stratigraphic and halokinetic Attractive features Reservoir is proven in wells 7316/5-1 and 7216/11-1S Source rock of Early Aptian age may be present along the Western Fault Margin Indication of Hauterivian source rock in well 7219/8-1 Critical factors Presence of reservoir The area has been affected by late Tertiary/Quaternary tilting. Distribution of Barents Sea play models Paleogene 20 Depositional environment Shallow and deep marine Source rock Mainly Creataceous
Estimating undiscovered resources 05/05/201521 Play analysis, input grouping of prospects play maps database uncertainty Play analysis, output recoverable resources expected field sizes
In place volumes – 2006 and 2009 Reduced uncertainties and increased expectations
Changed recovery factor for liquids og gas Væske Gass
Conclusions 23 play models are defined in the Norwegian Barents Sea Reservoir rocks from the early Carboniferous to the Oligocene are represented Only eight are confirmed while 14 remains unconfirmed The expected in place volumes are estimated to 2200 M Sm 3 o.e. The expected recovery volumes are estimated to 900 M Sm 3 o.e. Large volumes to be discovered 05/05/201525