Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
31.10.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/10-6

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  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/10-6
    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.
    P&A
    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
    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.
    30/10-6
    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.
    Elf Petroleum Norge 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.
    712-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.
    302
    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,
    13.01.1992
    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.
    09.11.1992
    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.
    09.11.1994
    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.
    17.12.2003
    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.
    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.
    TARBERT FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    91.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5248.0
    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).
    5246.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    180
    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.
    MIDDLE 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.
    NESS FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 9' 13.65'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 12' 37.38'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6668957.09
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    456160.10
    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.
    1816

  • Wellbore history
    General
    The exploration well 30/10-6 is situated in the central part of block 30/10, approximately 10km north of the Odin Field. The structure is part of the Jurassic fault block system forming at NE-SW trending complex from the Frigg area to the Southeastern part of block 30/7. The objective of well 30/10-6 was to explore the hydrocarbon potential of the Middle Jurassic Brent Group. Top Brent was prognosed at 5120 m.
    Operations and results
    The well 30/10-6 was spudded 13 January 1992 by the semi submersible rig West Alpha and was completed the 11 November 1992 at a TD of 5250 in the Middle Jurassic Ness Formation of the Brent Group. Due to too much inclination of the well, it had to be spudded three times. The verticality was critical due to possible severe casing wear in a deep well. After the third spud the drill string got stuck at 620 m in the 26" section. Fishing was unsuccessful and as verticality was important the well was respudded again. If plugging is not considered, the total duration of the well was 206 days for the drilling part. This includes 22 days on the three first spuds and 184 days on the final well. Compared to the planned 114 days (114 = 125 -11 for P&A) this yields a total delay of 92 days. The well was drilled with Bentonite mud down to 1420 m, with gypsum mud from 1420 m to 4368 m, and with polymer mud from 4368 m to TD.
    A seismic reflector depth converted to 4850 m (+ /- 200m), was interpreted as a "Callovian Unconformity", possibly with sand stringers. This seismic reflector proved to be top Tarbert Formation at 4666 m. The Tarbert Formation could be divided into two an Upper Sand (4666 m to 4815 m) and a Lower Sand (4884.5 m to 5207 m) separated by a 70 m thick shale unit. The top part of the Upper Sand contained gas. It was not possible to establish a free water level or a gas/water contact. The reservoir characteristics were poor and commercial production was not found to be possible.
    The well was permanently plugged and abandoned as a gas discovery.
    Testing
    Four tests were performed in the Tarbert Formation, two in the Lower Sand and two in the Upper Sand.
    DST 1C in the lower part of the Lower Sand Unit (5008 m to 5045 m) produced no hydrocarbons at surface. The formation was found to be tight and water bearing.
    DST 2B in two zones in the upper part of the Lower Sand Unit (4899 m to 4912 m + 4930 m to 4965.2 m) produced dry gas in slugs. Gas gravity was 0.58.  The zones were found to be tight with trapped gas and water, with an uncertain gas/water contact. The produced dry gas could come from DST 4 permeable zone by channelling through liner annulus.
    DST 3 in the lower part of the Upper Sand Unit (4768 m to 4803 m) produced dry gas in slugs. Gas gravity was 0.62. The formation was found to be tight with trapped gas and water, with an uncertain gas/water contact. Produced dry gas could come from DST 4 permeable zone by channelling through liner annulus.
    DST 4 in the upper part of the Upper Sand Unit (4666 m to 4714 m) produced dry gas at a rate of 90000 Sm3/day and no water using an 8/64" choke. The gas was completely dry with no liquid at surface. Gas gravity was 0.62 and had chemical and isotopic composition similar to the gas recovered in DST 2B and DST 3.

  • 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]
    230.00
    5250.00

  • 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
    4663.0
    4671.8
    [m ]
    2
    4672.0
    4691.0
    [m ]
    3
    4691.0
    4693.4
    [m ]
    4
    4697.0
    4716.0
    [m ]
    5
    4946.0
    4964.0
    [m ]
    6
    4964.0
    4980.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    83.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4663-4666m
    Core photo at depth: 4666-4669m
    Core photo at depth: 4669-4671m
    Core photo at depth: 4672-4674m
    Core photo at depth: 4675-4678m
    4663-4666m
    4666-4669m
    4669-4671m
    4672-4674m
    4675-4678m
    Core photo at depth: 4678-4681m
    Core photo at depth: 4681-4684m
    Core photo at depth: 4684-4687m
    Core photo at depth: 4687-4689m
    Core photo at depth: 4689-4691m
    4678-4681m
    4681-4684m
    4684-4687m
    4687-4689m
    4689-4691m
    Core photo at depth: 4691-4693m
    Core photo at depth: 4697-4700m
    Core photo at depth: 4700-4703m
    Core photo at depth: 4703-4706m
    Core photo at depth: 4706-4709m
    4691-4693m
    4697-4700m
    4700-4703m
    4703-4706m
    4706-4709m
    Core photo at depth: 4709-4712m
    Core photo at depth: 4712-4714m
    Core photo at depth: 4714-4716m
    Core photo at depth: 4946-4949m
    Core photo at depth: 4949-4952m
    4709-4712m
    4712-4714m
    4714-4716m
    4946-4949m
    4949-4952m
    Core photo at depth: 4952-4955m
    Core photo at depth: 4955-4958m
    Core photo at depth: 4958-4961m
    Core photo at depth: 4961-4964m
    Core photo at depth: 4964-4967m
    4952-4955m
    4955-4958m
    4958-4961m
    4961-4964m
    4964-4967m
    Core photo at depth: 4967-4970m
    Core photo at depth: 4970-4973m
    Core photo at depth: 4973-4976m
    Core photo at depth: 4976-4979m
    Core photo at depth: 4979-4980m
    4967-4970m
    4970-4973m
    4973-4976m
    4976-4979m
    4979-4980m

  • 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
    205.0
    36
    206.0
    0.00
    LOT
    INTERM.
    20
    1410.0
    26
    1411.0
    1.83
    LOT
    INTERM.
    13 3/8
    3064.0
    17 1/2
    3065.0
    1.88
    LOT
    INTERM.
    9 5/8
    4353.0
    12 1/4
    4354.0
    2.20
    LOT
    LINER
    7
    5248.0
    8 1/2
    5248.0
    2.29
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    5008
    5045
    0.0
    1.1
    5008
    5045
    3.0
    2.0
    4899
    4965
    0.0
    2.1
    4899
    4965
    0.0
    2.2
    4899
    5250
    0.0
    3.0
    4768
    4803
    0.0
    4.0
    4666
    4714
    3.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    1.1
    2.0
    2.1
    2.2
    3.0
    4.0
    154
    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
    1.1
    2.0
    2.1
    2.2
    0.580
    3.0
    4.0
    90000
    0.620

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BGT DLL BHC GR AMS
    4740
    4948
    BGT DSI GR AMS
    4685
    5077
    BHC MSF DIL GR AMS
    4997
    5253
    CBL VDL GR
    1500
    3058
    CBL VDL GR
    3033
    4352
    CBL VDL GR
    4000
    4989
    CST GR
    2149
    2586
    CST GR
    2149
    2586
    CST GR
    3089
    4271
    CST GR
    4382
    5069
    CST GR
    5080
    5238
    CST GR
    5080
    5238
    DIL BHC LDL GR AMS
    3062
    4358
    DIL MSFL GR AMS
    4910
    5077
    DITE BHC GR AMS
    4358
    5051
    DLL BGT GR AMS
    4630
    4909
    DLL GR AMS
    5050
    5253
    DLL MSFL BHC GR AMS
    4358
    4844
    DLL MSFL GR AMS
    4650
    5042
    FMI MS DIP
    4358
    5077
    FMS GR AMS
    5074
    5253
    LDL CNL BGT AMS
    4650
    4944
    LDL CNL NGL AMS
    3575
    3725
    LDL CNL NGL AMS
    4358
    4840
    LDL CNL NGL AMS
    4650
    5052
    LDL CNL NGL BHC
    4915
    5077
    MFCT
    0
    0
    MFCT GR
    110
    4830
    MWD
    205
    5050
    NGL CNL LDL AMS
    5000
    5253
    PSV
    1080
    3000
    PSV
    2700
    4350
    QSST DIL BHC LDL GR AMS
    1407
    3065
    RFT GR AMS
    0
    4849
    RFT GR AMS
    4666
    4810
    RFT GR AMS
    4884
    4903
    RFT GR AMS
    4914
    4939
    RFT GR AMS
    4915
    4939
    RFT GR AMS
    4969
    5067
    SHDT GR AMS
    1407
    3063
    SHDT GR AMS
    3062
    4286
    SHDT GR CAL
    4357
    4830
    SHDT GR CAL CCL CBL
    109
    4285

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.73

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.74

  • 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
    38.46

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    100
    1.89
    23.0
    WATER BASED
    105
    1.89
    WATER BASED
    130
    1.05
    WATER BASED
    133
    1.05
    WATER BASED
    150
    1.70
    20.0
    WATER BASED
    205
    1.05
    1.0
    WATER BASED
    300
    1.50
    WATER BASED
    305
    1.06
    25.0
    WATER BASED
    324
    1.05
    WATER BASED
    335
    1.09
    15.0
    WATER BASED
    500
    1.05
    10.0
    WATER BASED
    643
    1.05
    WATER BASED
    850
    1.08
    25.0
    WATER BASED
    870
    1.09
    16.0
    WATER BASED
    1170
    1.10
    27.0
    WATER BASED
    1300
    1.50
    15.0
    WATER BASED
    1350
    1.11
    16.0
    WATER BASED
    1370
    1.12
    17.0
    WATER BASED
    1377
    1.09
    15.0
    WATER BASED
    1385
    1.11
    15.0
    WATER BASED
    1420
    1.12
    6.0
    WATER BASED
    1500
    1.89
    30.0
    WATER BASED
    1544
    1.15
    24.0
    WATER BASED
    1778
    1.25
    22.0
    WATER BASED
    1846
    1.30
    27.0
    WATER BASED
    1986
    1.35
    26.0
    WATER BASED
    2107
    1.36
    44.0
    WATER BASED
    2179
    1.36
    25.0
    WATER BASED
    2187
    1.37
    26.0
    WATER BASED
    2193
    1.37
    35.0
    WATER BASED
    2246
    1.37
    32.0
    WATER BASED
    2273
    1.37
    39.0
    WATER BASED
    2364
    1.37
    39.0
    WATER BASED
    2471
    1.37
    37.0
    WATER BASED
    2525
    1.36
    50.0
    WATER BASED
    2525
    1.36
    37.0
    WATER BASED
    2534
    1.89
    23.0
    WATER BASED
    2550
    1.89
    25.0
    WATER BASED
    2563
    1.36
    37.0
    WATER BASED
    2584
    1.36
    29.0
    WATER BASED
    2642
    1.36
    26.0
    WATER BASED
    2666
    1.36
    26.0
    WATER BASED
    2692
    1.36
    27.0
    WATER BASED
    2750
    1.36
    24.0
    WATER BASED
    2800
    1.89
    WATER BASED
    2860
    1.36
    25.0
    WATER BASED
    2891
    1.59
    19.0
    WATER BASED
    2947
    1.36
    25.0
    WATER BASED
    2970
    1.36
    23.0
    WATER BASED
    3055
    1.36
    24.0
    WATER BASED
    3076
    1.36
    23.0
    WATER BASED
    3083
    1.38
    23.0
    WATER BASED
    3200
    1.37
    23.0
    WATER BASED
    3220
    1.37
    23.0
    WATER BASED
    3221
    1.37
    23.0
    WATER BASED
    3230
    1.37
    24.0
    WATER BASED
    3288
    1.37
    22.0
    WATER BASED
    3636
    1.37
    21.0
    WATER BASED
    3644
    1.40
    25.0
    WATER BASED
    3692
    1.43
    20.0
    WATER BASED
    3755
    1.43
    23.0
    WATER BASED
    3795
    1.47
    24.0
    WATER BASED
    3816
    1.48
    25.0
    WATER BASED
    3816
    1.48
    26.0
    WATER BASED
    4006
    1.72
    24.0
    WATER BASED
    4060
    1.72
    25.0
    WATER BASED
    4124
    1.74
    26.0
    WATER BASED
    4150
    2.14
    36.0
    WATER BASED
    4167
    1.75
    25.0
    WATER BASED
    4183
    2.14
    37.0
    WATER BASED
    4210
    1.75
    26.0
    WATER BASED
    4260
    1.75
    22.0
    WATER BASED
    4292
    1.75
    23.0
    WATER BASED
    4321
    1.78
    20.0
    WATER BASED
    4336
    1.80
    20.0
    WATER BASED
    4353
    1.85
    22.0
    WATER BASED
    4368
    1.85
    21.0
    WATER BASED
    4371
    1.89
    23.0
    WATER BASED
    4373
    1.96
    23.0
    WATER BASED
    4388
    1.95
    23.0
    WATER BASED
    4433
    1.96
    28.0
    WATER BASED
    4440
    1.95
    25.0
    WATER BASED
    4458
    1.95
    25.0
    WATER BASED
    4493
    1.95
    25.0
    WATER BASED
    4500
    1.95
    26.0
    WATER BASED
    4524
    1.95
    25.0
    WATER BASED
    4535
    2.14
    36.0
    WATER BASED
    4553
    2.14
    36.0
    WATER BASED
    4574
    1.95
    26.0
    WATER BASED
    4619
    1.95
    26.0
    WATER BASED
    4663
    2.08
    30.0
    WATER BASED
    4672
    2.10
    27.0
    WATER BASED
    4724
    2.14
    33.0
    WATER BASED
    4725
    2.14
    0.5
    WATER BASED
    4730
    2.10
    44.0
    WATER BASED
    4794
    1.95
    24.0
    WATER BASED
    4825
    2.10
    27.0
    WATER BASED
    4845
    2.10
    30.0
    WATER BASED
    4860
    2.10
    38.0
    WATER BASED
    4865
    2.10
    42.0
    WATER BASED
    4910
    2.10
    38.0
    WATER BASED
    4946
    2.10
    42.0
    WATER BASED
    4968
    2.10
    30.0
    WATER BASED
    4970
    2.10
    36.0
    WATER BASED
    4980
    2.10
    48.0
    WATER BASED
    4985
    2.10
    48.0
    WATER BASED
    4985
    2.10
    46.0
    WATER BASED
    5048
    2.10
    36.0
    WATER BASED
    5065
    2.10
    53.0
    WATER BASED
    5075
    2.10
    40.0
    WATER BASED
    5078
    2.04
    32.0
    WATER BASED
    5097
    2.04
    54.0
    WATER BASED
    5151
    2.04
    48.0
    WATER BASED
    5177
    2.04
    55.0
    WATER BASED
    5250
    2.04
    48.0
    WATER BASED

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    4610.0
    [m]
    DC
    CGG
    4622.5
    [unknown]
    DC
    CGG
    4630.0
    [m]
    DC
    CGG
    4645.0
    [m]
    DC
    CGG
    4655.0
    [m]
    DC
    CGG
    4660.0
    [m]
    DC
    CGG
    4665.0
    [m]
    C
    CGG
    4689.0
    [m]
    C
    CGG
    4690.0
    [m]
    C
    CGG
    4693.3
    [m]
    C
    CGG
    4714.0
    [m]
    C
    CGG
    4715.2
    [m]
    C
    CGG
    4716.0
    [m]
    C
    CGG
    4717.5
    [m]
    DC
    CGG
    4827.5
    [m]
    DC
    CGG
    4835.0
    [m]
    DC
    CGG
    4860.0
    [m]
    DC
    CGG
    4870.0
    [m]
    DC
    CGG
    4977.5
    [m]
    C
    CGG
    4978.0
    [m]
    C
    CGG