Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
26.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/9-13 S

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/9-13 S
    Type
    Wellbore type. Legal values: EXPLORATION, DEVELOPMENT, OTHER (see 'Purpose' for more information)
    EXPLORATION
    Purpose
    Final classification of the wellbore.

    Legal values for exploration wellbores:
    WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS.

    Legal values for development wellbores:
    OBSERVATION, PRODUCTION, INJECTION, INJECTION-CCS, OBSERVATION-CCS.

    Legal values for other wellbores:
    SOIL DRILLING (drilling in connection with track surveys and other subsurface surveys to investigate the soil conditions prior to placement of facilities),
    SHALLOW GAS (drilling to investigate shallow gas before the first 'real' drilling on the location),
    PILOT (drilling to investigate the geology and fluid connectors for location of the main wellbore),
    SCIENTIFIC (drilling according to Law of Scientific research and exploration),
    STRATIGRAPHIC (driling according to Law of Petroleum activities §2-1).
    WILDCAT
    Status
    Status for the wellbore. Legal values are:

    BLOWOUT: A blowout has occurred in the well.
    CLOSED: A development wellbore that has been closed in a shorter or longer periode. Also applies to development wellbores where drilling is completed, but production/injection has not yet been reported.
    DRILLING: The well is in the drilling phase - can be active drilling, logging, testing or plugging,
    JUNKED: The drilling operation has been terminated due to technical problems.
    P&A: Exploration: The well is plugged and abandoned, and can not be reentered for further use. Development wells: The production/injection from/to the well is stopped and the well is plugged. The wellhead is removed or else made unavailable for further well operations.
    PLUGGED: The wellbore has been plugged, but the upper parts of the wellbore can be re-used. A sidetrack might be drilled at a later stage.
    PRODUCING: It was produced from the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    INJECTING: It was injected to the wellbore at the time of the operators last monthly report to the Norwegian Offshore Directorate.
    PREDRILLED: The upper part of the well has been drilled, usually as part of a batch-drilling campaign covering several wellbores.
    RE-CLASS TO DEV: Exploration wellbore that is reclassified to a development wellbore.
    RE-CLASS TO TEST: Exploration wellbore that is reclassified to test production.
    SUSPENDED: The drilling operation in the wellbore has been temporarily stopped. The current plan is to continue drilling later on.
    SUSPENDED
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/9-13
    Production licence
    Official designation of the production licence the wellbore was drilled or planned to be drilled from ( well head posistion).
    Drilling operator
    Name of the licensee starting the drilling operation on behalf of the active production license (well head position). This will usually equal the operator of the production license.
    Norsk Hydro Produksjon AS
    Drill permit
    The drilling permit number together with the version of the drilling permit as stated in the drilling permit granted by the Norwegian Offshore Directorate.
    688-L
    Drilling facility
    Norwegian Offshore Directorate's name of the facility which the wellbore was drilled from.
    Drilling days
    Number of days from wellbore entry to wellbore completion.
    99
    Entered date
    The date when he wellbore was spudded. For sidetracks: The date when new formation was drilled by kicking off from the mother-wellbore,
    05.07.1991
    Completed date
    Exploration wellbores from moveable facilities:
    For floating facilities - date when anchor handling is started. For jackups - date the jacking-down started. Exploration wellbores from fixed facilities and all development wellbores:
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    Date when the wellbore is at total depth, and last casing, liner or screen is set. In case of immediate plugging of the wellbore, completed date equals the date the last plug i set in the wellbore.
    11.10.1991
    Release date
    Date when raw data which has been reported to the authorities from the wellbore is not confidential any longer. Normally 2 years after finishing the drilling. May be earlier if the area of the production license is relinquished.
    11.10.1993
    Publication date
    Date quality control of the wellbore information was completed, so it can be published on the internet as a 'Well Data Summary Sheet' wellbore with more information available than other wellbores.
    29.06.2004
    Purpose - planned
    Pre-drill purpose of the wellbore. Legal values for exploration wellbores: WILDCAT, APPRAISAL, WILDCAT-CCS, APPRAISAL-CCS. Example of legal values for development wellbores: OBSERVATION, PRODUCTION, INJECTION.
    WILDCAT
    Content
    For exploration wellbores, status of discovery.

    Legal values:
    DRY, SHOWS (trace amounts of hydrocarbons), GAS, GAS/CONDENSATE, OIL or OIL/GAS.
    SHOWS (GAS SHOWS, OIL SHOWS or OIL/GAS SHOWS) are detected as fluorescent cut (organic extract), petroleum odour, or visual stain on cuttings or cores, or as increased gas reading on the mud-loggers gas detection equipment.
    Legal values for WILDCAT-CCS and APPRAISAL-CCS: WATER

    For development wellbores, type of produced/injected fluid.
    Legal values:
    WATER, CUTTINGS, NOT AVAILABLE, OIL, GAS/CONDENSATE, OIL/GAS, CO2, GAS, WATER/GAS, NOT APPLICABLE.
    OIL/GAS
    Discovery wellbore
    Indicator which tells if the wellbore made a new discovery. Legal values: YES, NO. Prior to press-release or other information regarding drilling results, the indicator will be “NO” as a default.
    YES
    1st level with HC, age
    Age of lithostratigraphic unit, 1st level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE. See also Norwegian Offshore Directorate bulletins.
    MIDDLE JURASSIC
    1st level with HC, formation
    Name of lithostartigraphic unit, 1st level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP. See also Norwegian Offshore Directorate bulletins.
    INTRA HEATHER FM SS
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd level, where hydrocarbons were encountered. Shown only for released wells. Examples of legal values: BASEMENT, COOK FM, EKOFISK FM, HEIMDAL FM, SANDNES FM, SOGNEFJORD FM, TARBERT FM, BRENT GP.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    106.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4027.0
    Final vertical depth (TVD) [m RKB]
    Vertical elevation from total depth to kelly bushing. Shown only for released wells. Referred to as true vertical depth (TVD).
    3964.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    31.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    140
    Oldest penetrated age
    Age (according to Geologic Time Scale 2004 by F. M. Gradstein, et al. (2004)) of the oldest penetrated formation. May differ from age at TD for example in deviated wellbores. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EARLY PERMIAN, EARLY TRIASSIC, EOCENE.
    EARLY JURASSIC
    Oldest penetrated formation
    Name of the oldest lithostratigraphic unit penetrated by the wellbore. Shown only for released wells. In most wellbores this is formation or group at total depth. May differ from formation or group at TD for example in wellbores drilled with high deviation or through faults. Examples of legal values: AMUNDSEN FM, BALDER FM, BASEMENT, BLODØKS FM, BRYNE FM, BURTON FM, COOK FM, DRAKE FM, DRAUPNE FM, EKOFISK FM, DUNLIN GP.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 21' 37.69'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 43' 17.78'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6691746.63
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    484640.30
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    31
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    1811

  • Wellbore history
    General
    The primary objective of the 30/9-13 S well was to prove hydrocarbon potential in the Tarbert Formation in the G-East prospect, south west of the Oseberg Field. The well should define fluid contacts in the prospect and test the sealing capacity of the eastern fault. The location was chosen to drill through untruncated Tarbert Formation, and it should leave a minimum of untested reserves up dip in order to establish the fluid contacts in the lower part of the Tarbert Formation.
    As secondary objectives the well should test the resource potential within the Ness, Oseberg, Rannoch, Etive, Cook and Statfjord Formations. The well was planned deviated due to a very high amplitude reflection, resulting in a shallow gas
    warning for a sand layer at 496 ± 10 m.
    Operations and results
    Wildcat well 30/9-13 S was spudded with the semi-submersible installation Vildkat Explorer on 5 May 1991 and drilled to a total depth of 4027 m in Early Jurassic Statfjord Formation sandstone. The well was drilled with seawater and hi-vis pills down to 1030 m, with KCl/polymer mud from 1030 m to 3031 m, and with Thermadrill/KCl/polymer mud from 3031 m to TD. The well was drilled vertical to the 13 3/8" casing shoe and was kicked off from there using a steerable motor. A maximum inclination of 31 ° was obtained at 1434 m. At 1483 m the steerable system was pulled and a drop assembly was run in hole to continue drilling. Intra Heather Formation Sandstone was encountered at 2959 m in the 12 l/4" hole before the planned 9 5/8" casing point had been reached. The well was plugged back and casing was set above the hydrocarbon-bearing interval. On drilling out of the casing the well was sidetracked down to the top of the Heather Formation at 2963 m. The greater part of the Heather Formation proved to be sand with a total net gas column of 28.5 m. A total oil reservoir zone of 77 m with a 60 m net pay zone was identified. A Free Oil Level (FOL) was encountered in the Heather Formation and an Oil Water Contact (OWC) was interpreted from logs at 3101 m in the Tarbert
    Formation. The Statfjord Formation consisted of water bearing moderately over pressured sandstones of low permeability. A total of 11 conventional cores were cut continuously from 2957 m through the Heather GOC and the Tarbert OWC down to 3154 m at the base of the Tarbert Formation. Wire line RFT fluid samples were taken at 3097.1 m in the Tarbert Formation (gas/water/mud filtrate), at 3025.6 m in base Heather Formation (gas/water/mud filtrate/trace of oil), at 3997.1 m in the Statfjord Formation (gas/water/mud filtrate), and at 4012.8 m in the Statfjord Formation (water and mud filtrate without any gas or oil). A total of 60 sidewall cores were attempted and 35 were recovered. The well was suspended as an oil and gas discovery on 11 October 1991.
    Testing
    Tree DST tests were performed. Test 1 was performed in the interval 3086.5 m to 3094.5 m in middle Tarbert yielding a maximum flow rate of 792 Sm3/d oil and 120983 Sm3/d gas through a 19.05 mm choke. Test 2 was performed in the interval 3023.9 m to 3072.9 m in the upper Tarbert yielding a maximum flow rate of 535 Sm3/d oil and 107458 Sm3/d gas through a 19.05 mm choke. Test 3 was performed in the interval 2958.1 m to 2986.1 m in Intra Heather Sandstone and yielded 90 Sm3/d oil and 459552 Sm3/d gas through a 28.575 mm choke.

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    YES
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    1030.00
    4027.00

  • Cores at the Norwegian Offshore Directorate
    Cores at the Norwegian Offshore Directorate
    Core sample number
    Core sample - top depth
    Core sample - bottom depth
    Core sample depth - uom
    1
    2957.0
    2975.0
    [m ]
    2
    2975.0
    2985.0
    [m ]
    3
    2985.0
    3018.0
    [m ]
    4
    3018.0
    3040.7
    [m ]
    5
    3041.0
    3066.7
    [m ]
    6
    3067.0
    3086.0
    [m ]
    7
    3086.0
    3093.6
    [m ]
    8
    3095.0
    3122.0
    [m ]
    9
    3122.0
    3150.4
    [m ]
    10
    3150.2
    3178.0
    [m ]
    11
    3179.0
    3188.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    228.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2957-2962m
    Core photo at depth: 2962-2967m
    Core photo at depth: 2967-2972m
    Core photo at depth: 2972-2977m
    Core photo at depth: 2977-2982m
    2957-2962m
    2962-2967m
    2967-2972m
    2972-2977m
    2977-2982m
    Core photo at depth: 2982-2984m
    Core photo at depth: 2985-2990m
    Core photo at depth: 2990-2995m
    Core photo at depth: 2995-3000m
    Core photo at depth: 3000-3005m
    2982-2984m
    2985-2990m
    2990-2995m
    2995-3000m
    3000-3005m
    Core photo at depth: 3005-3010m
    Core photo at depth: 3010-3014m
    Core photo at depth: 3014-3019m
    Core photo at depth: 3019-3024m
    Core photo at depth: 3024-3029m
    3005-3010m
    3010-3014m
    3014-3019m
    3019-3024m
    3024-3029m
    Core photo at depth: 3029-3034m
    Core photo at depth: 3034-3039m
    Core photo at depth: 3039-3044m
    Core photo at depth: 3044-3049m
    Core photo at depth: 3049-3054m
    3029-3034m
    3034-3039m
    3039-3044m
    3044-3049m
    3049-3054m
    Core photo at depth: 3054-3059m
    Core photo at depth: 3059-3064m
    Core photo at depth: 3064-3069m
    Core photo at depth: 3069-3074m
    Core photo at depth: 3074-3079m
    3054-3059m
    3059-3064m
    3064-3069m
    3069-3074m
    3074-3079m
    Core photo at depth: 3079-3084m
    Core photo at depth: 3084-3089m
    Core photo at depth: 3089-3093m
    Core photo at depth: 3059-3100m
    Core photo at depth: 3100-3105m
    3079-3084m
    3084-3089m
    3089-3093m
    3059-3100m
    3100-3105m
    Core photo at depth: 3105-3110m
    Core photo at depth: 3110-3115m
    Core photo at depth: 3115-3120m
    Core photo at depth: 3120-3125m
    Core photo at depth: 3125-3130m
    3105-3110m
    3110-3115m
    3115-3120m
    3120-3125m
    3125-3130m
    Core photo at depth: 3130-3135m
    Core photo at depth: 3135-3140m
    Core photo at depth: 3140-3145m
    Core photo at depth: 3145-3150m
    Core photo at depth: 3150-3154m
    3130-3135m
    3135-3140m
    3140-3145m
    3145-3150m
    3150-3154m
    Core photo at depth: 3154-3159m
    Core photo at depth: 3159-3164m
    Core photo at depth: 3164-3169m
    Core photo at depth: 3169-3174m
    Core photo at depth: 3174-3178m
    3154-3159m
    3159-3164m
    3164-3169m
    3169-3174m
    3174-3178m
    Core photo at depth: 3179-3184m
    Core photo at depth: 3184-3188m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3179-3184m
    3184-3188m

  • Oil samples at the Norwegian Offshore Directorate
    Oil samples at the Norwegian Offshore Directorate
    Test type
    Bottle number
    Top depth
    MD [m]
    Bottom depth
    MD [m]
    Fluid type
    Test time
    Samples available
    DST
    TEST1
    3086.50
    3094.50
    OIL
    14.09.1991 - 14:00
    YES
    DST
    TEST2
    3023.90
    3072.90
    29.09.1991 - 15:00
    YES
    DST
    DST3
    2958.10
    2986.10
    CONDENSATE
    04.10.1991 - 10:15
    YES

  • Casing and leak–off tests
    Casing and leak–off tests
    Casing type
    Casing diam.
    [inch]
    Casing depth
    [m]
    Hole diam.
    [inch]
    Hole depth
    [m]
    LOT/FIT mud eqv.
    [g/cm3]
    Formation test type
    CONDUCTOR
    30
    216.0
    36
    218.0
    0.00
    LOT
    INTERM.
    13 3/8
    1017.0
    17 1/2
    1020.0
    0.00
    LOT
    INTERM.
    9 5/8
    2876.0
    12 1/4
    2880.0
    1.88
    LOT
    LINER
    7
    4027.0
    8 1/2
    4027.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3086
    3095
    19.0
    2.0
    3024
    3073
    19.0
    3.0
    2958
    2986
    28.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    114
    2.0
    110
    3.0
    86
    Drill stem tests (DST)
    Test number
    Oil
    [Sm3/day]
    Gas
    [Sm3/day]
    Oil density
    [g/cm3]
    Gas grav. rel.air
    GOR
    [m3/m3]
    1.0
    792
    120983
    0.850
    0.730
    153
    2.0
    535
    107458
    0.840
    0.760
    201
    3.0
    90
    459522
    0.780
    0.720
    5099

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CST GR
    2487
    3004
    CST GR
    3386
    4021
    DIL LSS GR SP AMS
    3286
    4030
    DIL LSS LDL CNL NGT AMS
    2874
    3396
    DIL LSS LDL GR SP AMS
    1016
    3006
    DLL MSFL GR SP CAL AMS
    2700
    3002
    DLL MSFL GR SP CAL AMS
    2874
    3391
    DLL MSFL GR SP CAL AMS
    3940
    4026
    FMS4 GR AMS
    2925
    4029
    LDL CNL NGT CAL AMS
    3300
    4030
    MWD - GR RES DIR
    220
    4007
    RFT HP GR AMS
    2966
    3097
    RFT HP GR AMS
    2973
    3349
    RFT HP GR AMS
    3104
    3392
    RFT HP GR AMS
    3979
    4008
    RFT HP GR AMS
    3987
    4014
    VSP
    131
    3220

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.62

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.94

  • Documents – reported by the production licence (period for duty of secrecy expired)
    Documents – reported by the production licence (period for duty of secrecy expired)
    Document name
    Document format
    Document size [MB]
    pdf
    18.78

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    217
    1.05
    WATER BASED
    08.07.1991
    1030
    1.20
    WATER BASED
    10.07.1991
    1030
    1.20
    WATER BASED
    10.07.1991
    1052
    1.10
    11.0
    9.0
    WATER BASED
    15.07.1991
    1205
    1.12
    14.0
    14.0
    WATER BASED
    16.07.1991
    1486
    1.20
    16.0
    11.0
    WATER BASED
    16.07.1991
    1492
    1.20
    16.0
    11.0
    WATER BASED
    16.07.1991
    1685
    1.32
    20.0
    12.0
    WATER BASED
    16.07.1991
    1822
    1.33
    20.0
    11.0
    WATER BASED
    17.07.1991
    1960
    1.33
    22.0
    13.0
    WATER BASED
    18.07.1991
    2135
    1.32
    23.0
    14.0
    WATER BASED
    19.07.1991
    2249
    1.32
    22.0
    16.0
    WATER BASED
    23.07.1991
    2498
    1.31
    23.0
    15.0
    WATER BASED
    23.07.1991
    2498
    1.32
    24.0
    13.0
    WATER BASED
    23.07.1991
    2521
    1.32
    22.0
    11.0
    WATER BASED
    23.07.1991
    2579
    1.32
    19.0
    10.0
    WATER BASED
    24.07.1991
    2610
    1.33
    18.0
    10.0
    WATER BASED
    26.07.1991
    2675
    1.35
    19.0
    10.0
    WATER BASED
    30.07.1991
    2783
    1.35
    19.0
    9.0
    WATER BASED
    30.07.1991
    2786
    1.27
    11.0
    8.0
    WATER BASED
    10.10.1991
    2851
    1.35
    20.0
    9.0
    WATER BASED
    30.07.1991
    2880
    1.35
    21.0
    11.0
    WATER BASED
    02.08.1991
    2890
    1.35
    20.0
    11.0
    WATER BASED
    06.08.1991
    2890
    1.22
    12.0
    7.0
    WATER BASED
    06.08.1991
    2921
    1.22
    14.0
    9.0
    WATER BASED
    06.08.1991
    2963
    1.35
    23.0
    12.0
    WATER BASED
    31.07.1991
    2975
    1.23
    15.0
    8.0
    WATER BASED
    06.08.1991
    2993
    1.22
    15.0
    8.0
    WATER BASED
    07.08.1991
    3000
    1.26
    10.0
    8.0
    WATER BASED
    01.10.1991
    3009
    1.26
    7.0
    7.0
    WATER BASED
    07.10.1991
    3009
    1.26
    7.0
    7.0
    WATER BASED
    08.10.1991
    3009
    1.27
    10.0
    8.0
    WATER BASED
    01.10.1991
    3009
    1.27
    9.0
    9.0
    WATER BASED
    01.10.1991
    3009
    1.29
    4.0
    7.0
    WATER BASED
    02.10.1991
    3009
    1.27
    4.0
    7.0
    WATER BASED
    03.10.1991
    3009
    1.27
    8.0
    6.0
    WATER BASED
    04.10.1991
    3009
    1.27
    9.0
    6.0
    WATER BASED
    07.10.1991
    3009
    1.26
    6.0
    4.0
    WATER BASED
    07.10.1991
    3009
    1.27
    11.0
    8.0
    WATER BASED
    09.10.1991
    3031
    1.35
    21.0
    9.0
    WATER BASED
    01.08.1991
    3031
    1.35
    20.0
    9.0
    WATER BASED
    02.08.1991
    3033
    1.22
    20.0
    7.0
    WATER BASED
    08.08.1991
    3067
    1.22
    15.0
    6.0
    WATER BASED
    09.08.1991
    3083
    1.26
    8.0
    8.0
    WATER BASED
    27.09.1991
    3083
    1.26
    8.0
    6.0
    WATER BASED
    23.09.1991
    3083
    1.26
    7.0
    7.0
    WATER BASED
    24.09.1991
    3083
    1.26
    8.0
    6.0
    WATER BASED
    25.09.1991
    3083
    1.26
    8.0
    8.0
    WATER BASED
    27.09.1991
    3083
    1.26
    8.0
    7.0
    WATER BASED
    01.10.1991
    3095
    1.22
    12.0
    6.0
    WATER BASED
    12.08.1991
    3122
    1.22
    14.0
    7.0
    WATER BASED
    12.08.1991
    3164
    1.22
    12.0
    7.0
    WATER BASED
    12.08.1991
    3194
    1.22
    14.0
    8.0
    WATER BASED
    14.08.1991
    3223
    1.22
    13.0
    7.0
    WATER BASED
    14.08.1991
    3316
    1.22
    12.0
    7.0
    WATER BASED
    16.08.1991
    3328
    1.26
    11.0
    5.0
    WATER BASED
    10.09.1991
    3328
    1.26
    8.0
    6.0
    WATER BASED
    16.09.1991
    3328
    1.26
    12.0
    7.0
    WATER BASED
    10.09.1991
    3328
    1.26
    11.0
    7.0
    WATER BASED
    10.09.1991
    3328
    1.26
    11.0
    5.0
    WATER BASED
    10.09.1991
    3328
    1.26
    11.0
    5.0
    WATER BASED
    12.09.1991
    3328
    1.26
    10.0
    5.0
    WATER BASED
    12.09.1991
    3328
    1.26
    10.0
    4.0
    WATER BASED
    16.09.1991
    3328
    1.26
    11.0
    5.0
    WATER BASED
    16.09.1991
    3328
    1.26
    12.0
    7.0
    WATER BASED
    16.09.1991
    3328
    1.26
    8.0
    6.0
    WATER BASED
    17.09.1991
    3328
    1.26
    12.0
    7.0
    WATER BASED
    18.09.1991
    3328
    1.26
    12.0
    7.0
    WATER BASED
    20.09.1991
    3328
    1.26
    8.0
    8.0
    WATER BASED
    20.09.1991
    3328
    1.26
    10.0
    6.0
    WATER BASED
    23.09.1991
    3328
    1.26
    9.0
    6.0
    WATER BASED
    23.09.1991
    3385
    1.26
    16.0
    7.0
    WATER BASED
    16.08.1991
    3396
    1.26
    15.0
    7.0
    WATER BASED
    20.08.1991
    3396
    1.26
    15.0
    6.0
    WATER BASED
    20.08.1991
    3396
    1.26
    14.0
    6.0
    WATER BASED
    20.08.1991
    3396
    1.26
    13.0
    5.0
    WATER BASED
    22.08.1991
    3396
    1.26
    15.0
    7.0
    WATER BASED
    20.08.1991
    3399
    1.26
    15.0
    7.0
    WATER BASED
    22.08.1991
    3425
    1.26
    16.0
    7.0
    WATER BASED
    23.08.1991
    3544
    1.26
    16.0
    7.0
    WATER BASED
    27.08.1991
    3597
    1.26
    15.0
    6.0
    WATER BASED
    27.08.1991
    3757
    1.26
    20.0
    8.0
    WATER BASED
    27.08.1991
    3860
    1.26
    18.0
    7.0
    WATER BASED
    27.08.1991
    3963
    1.26
    22.0
    8.0
    WATER BASED
    28.08.1991
    3991
    1.26
    20.0
    8.0
    WATER BASED
    29.08.1991
    4027
    1.26
    18.0
    6.0
    WATER BASED
    02.09.1991
    4027
    1.26
    19.0
    7.0
    WATER BASED
    02.09.1991
    4027
    1.25
    19.0
    8.0
    WATER BASED
    02.09.1991
    4027
    1.25
    19.0
    8.0
    WATER BASED
    03.09.1991
    4027
    1.27
    20.0
    8.0
    WATER BASED
    04.09.1991
    4027
    1.27
    14.0
    8.0
    WATER BASED
    06.09.1991
    4027
    1.26
    20.0
    6.0
    WATER BASED
    02.09.1991
    4027
    1.27
    14.0
    8.0
    WATER BASED
    06.09.1991

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2120.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2240.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2300.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2410.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2487.0
    [m]
    SWC
    HYDRO
    2510.0
    [m]
    DC
    RRI
    2540.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2605.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2720.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2840.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2902.0
    [m]
    DC
    RRI
    2922.0
    [m]
    SWC
    HYDRO
    2929.0
    [m]
    SWC
    RRI
    2933.0
    [m]
    SWC
    RRI
    2939.0
    [m]
    SWC
    RRI
    2943.0
    [m]
    SWC
    RRI
    2944.0
    [m]
    SWC
    HYDRO
    2945.0
    [m]
    SWC
    HYDRO
    2947.0
    [m]
    SWC
    HYDRO
    2951.0
    [m]
    SWC
    HYDRO
    2955.0
    [m]
    SWC
    HYDRO
    2957.0
    [m]
    C
    HYDRO
    2958.0
    [m]
    C
    HYDRO
    2959.0
    [m]
    C
    HYDRO
    2960.0
    [m]
    C
    HYDRO
    2963.0
    [m]
    C
    HYDRO
    2965.0
    [m]
    C
    RRI
    2969.0
    [m]
    C
    HYDRO
    2969.0
    [m]
    SWC
    HYDRO
    2973.0
    [m]
    C
    HYDRO
    2979.0
    [m]
    SWC
    HYDRO
    2980.0
    [m]
    C
    HYDRO
    2986.0
    [m]
    SWC
    HYDRO
    2987.0
    [m]
    C
    HYDRO
    2992.0
    [m]
    C
    HYDRO
    2993.0
    [m]
    SWC
    HYDRO
    2998.0
    [m]
    SWC
    HYDRO
    2999.0
    [m]
    C
    HYDRO
    3000.0
    [m]
    SWC
    HYDRO
    3004.0
    [m]
    SWC
    HYDRO
    3004.0
    [m]
    C
    HYDRO
    3005.0
    [m]
    DC
    RRI
    3009.0
    [m]
    C
    HYDRO
    3016.0
    [m]
    C
    HYDRO
    3018.0
    [m]
    C
    HYDRO
    3020.0
    [m]
    C
    HYDRO
    3021.0
    [m]
    C
    HYDRO
    3022.0
    [m]
    C
    HYDRO
    3024.0
    [m]
    C
    HYDRO
    3025.0
    [m]
    C
    HYDRO
    3028.0
    [m]
    C
    HYDRO
    3032.0
    [m]
    DC
    RRI
    3033.0
    [m]
    C
    HYDRO
    3048.0
    [m]
    C
    HYDRO
    3060.0
    [m]
    C
    HYDRO
    3071.0
    [m]
    C
    HYDRO
    3077.0
    [m]
    C
    HYDRO
    3084.0
    [m]
    C
    HYDRO
    3085.0
    [m]
    C
    HYDRO
    3091.0
    [m]
    C
    HYDRO
    3095.0
    [m]
    C
    HYDRO
    3100.0
    [m]
    C
    HYDRO
    3103.0
    [m]
    C
    HYDRO
    3105.0
    [m]
    C
    HYDRO
    3115.0
    [m]
    C
    HYDRO
    3119.0
    [m]
    C
    HYDRO
    3124.0
    [m]
    C
    HYDRO
    3128.0
    [m]
    C
    HYDRO
    3129.0
    [m]
    C
    HYDRO
    3130.0
    [m]
    C
    RRI
    3132.0
    [m]
    C
    HYDRO
    3136.0
    [m]
    C
    HYDRO
    3142.0
    [m]
    C
    HYDRO
    3146.0
    [m]
    C
    HYDRO
    3152.0
    [m]
    C
    HYDRO
    3157.0
    [m]
    C
    HYDRO
    3163.0
    [m]
    C
    HYDRO
    3164.0
    [m]
    C
    HYDRO
    3169.0
    [m]
    C
    HYDRO
    3176.0
    [m]
    C
    HYDRO
    3183.0
    [m]
    C
    HYDRO
    3187.0
    [m]
    C
    HYDRO
    3188.0
    [m]
    C
    HYDRO
    3202.0
    [m]
    DC
    RRI
    3210.0
    [m]
    DC
    RRI
    3217.0
    [m]
    DC
    RRI
    3225.0
    [m]
    DC
    RRI
    3232.0
    [m]
    DC
    RRI
    3240.0
    [m]
    DC
    RRI
    3247.0
    [m]
    DC
    RRI
    3255.0
    [m]
    DC
    RRI
    3262.0
    [m]
    DC
    RRI
    3270.0
    [m]
    DC
    RRI
    3277.0
    [m]
    DC
    RRI
    3285.0
    [m]
    DC
    RRI
    3292.0
    [m]
    DC
    RRI
    3300.0
    [m]
    DC
    RRI
    3307.0
    [m]
    DC
    RRI
    3315.0
    [m]
    DC
    RRI
    3322.0
    [m]
    DC
    RRI
    3330.0
    [m]
    DC
    RRI
    3337.0
    [m]
    DC
    RRI
    3360.0
    [m]
    DC
    RRI
    3367.0
    [m]
    DC
    RRI
    3375.0
    [m]
    DC
    RRI
    3386.0
    [m]
    SWC
    HYDRO
    3390.0
    [m]
    DC
    RRI
    3397.0
    [m]
    DC
    RRI
    3404.0
    [m]
    SWC
    HYDRO
    3412.0
    [m]
    DC
    RRI
    3420.0
    [m]
    DC
    RRI
    3425.0
    [m]
    DC
    RRI
    3435.0
    [m]
    DC
    RRI
    3445.0
    [m]
    DC
    RRI
    3450.0
    [m]
    DC
    RRI
    3460.0
    [m]
    DC
    RRI
    3470.0
    [m]
    DC
    RRI
    3480.0
    [m]
    SWC
    HYDRO
    3490.0
    [m]
    DC
    RRI
    3500.0
    [m]
    DC
    RRI
    3510.0
    [m]
    DC
    RRI
    3520.0
    [m]
    DC
    RRI
    3530.0
    [m]
    DC
    RRI
    3540.0
    [m]
    DC
    RRI
    3550.0
    [m]
    DC
    RRI
    3560.0
    [m]
    DC
    RRI
    3570.0
    [m]
    DC
    RRI
    3590.0
    [m]
    DC
    RRI
    3600.0
    [m]
    DC
    RRI
    3620.0
    [m]
    DC
    RRI
    3627.0
    [m]
    SWC
    HYDRO
    3640.0
    [m]
    DC
    RRI
    3650.0
    [m]
    DC
    RRI
    3660.0
    [m]
    DC
    RRI
    3670.0
    [m]
    DC
    RRI
    3680.0
    [m]
    DC
    RRI
    3690.0
    [m]
    DC
    RRI
    3700.0
    [m]
    DC
    RRI
    3710.0
    [m]
    DC
    RRI
    3720.0
    [m]
    DC
    RRI
    3730.0
    [m]
    DC
    RRI
    3736.0
    [m]
    C
    HYDRO
    3740.0
    [m]
    SWC
    HYDRO
    3750.0
    [m]
    DC
    RRI
    3759.0
    [m]
    DC
    RRI
    3770.0
    [m]
    DC
    RRI
    3780.0
    [m]
    DC
    RRI
    3790.0
    [m]
    DC
    RRI
    3800.0
    [m]
    DC
    RRI
    3810.0
    [m]
    DC
    RRI
    3820.0
    [m]
    DC
    RRI
    3830.0
    [m]
    DC
    RRI
    3840.0
    [m]
    DC
    RRI
    3850.0
    [m]
    DC
    RRI
    3858.0
    [m]
    SWC
    HYDRO
    3870.0
    [m]
    DC
    RRI
    3880.0
    [m]
    DC
    RRI
    3890.0
    [m]
    DC
    RRI
    3900.0
    [m]
    DC
    RRI
    3910.0
    [m]
    DC
    RRI
    3920.0
    [m]
    DC
    RRI
    3930.0
    [m]
    DC
    RRI
    3940.0
    [m]
    DC
    RRI
    3950.0
    [m]
    DC
    RRI
    3964.0
    [m]
    SWC
    HYDRO
    3970.0
    [m]
    DC
    RRI
    3983.0
    [m]
    SWC
    HYDRO
    3990.0
    [m]
    DC
    RRI
    3997.0
    [m]
    SWC
    HYDRO
    4007.0
    [m]
    SWC
    HYDRO
    4027.0
    [m]
    DC
    RRI