Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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26.11.2024 - 01:27
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6506/12-4

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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.
    6506/12-4
    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.
    NORWEGIAN SEA
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6506/12-4
    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.
    Den norske stats oljeselskap a.s
    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.
    460-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.
    143
    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,
    24.03.1985
    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.
    13.08.1985
    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.
    13.08.1987
    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.
    02.03.2004
    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.
    SHOWS
    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.
    NO
    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.
    257.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4457.0
    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).
    4455.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    155
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 12' 46.97'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 43' 30.37'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7234298.14
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    393591.29
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    475

  • Wellbore history
    General
    Wildcat well 6506/12-4 was drilled on the Alpha north segment in the northern part of the Smørbukk field, Haltenbanken. The primary objective was to test the hydrocarbon bearing potential of Middle Jurassic Sandstones.
    Secondary objectives were to test Early Jurassic sandstones within the coal beds, and possible sand development within the Cretaceous. The prognosed depth was 4457 m or rocks of Triassic age to satisfy the licence commitment.
    The well is the typewell for the Melke, Springar, and Nise Formations, and reference well for the Viking and Cromer Knoll Groups and the Lange, Lysing, and Kvitnos Formations (NPD Bulletin no 4)
    Operations and results
    Wildcat well 6506/12-4 was spudded with Dyvi Offshore installation Dyvi Stena 24 March 1985 and drilled to TD at 4457 m in the Early Jurassic Åre Formation. The well was drilled with seawater and hi-vis pills down to 680 m where a shallow gas pocket caused the well to flow. The gas was led through the diverter system and mud weight was increased. This led to lost circulation, but control was gradually regained after pumping LCM pills. A cement plug was set between 600 m and 680 m. The 20" casing was set shallow at 622 m and drilling commenced with a Gypsum / Lignosulphonate mud system to the 8 1/2" section at 3936 m from where a weighted lignosulphonate mud system was used the rest of he well bore down to TD. During coring operation, at 3978 m, a water kick was experienced, but was brought under control. During cleanup at TD the drill string got stuck. While attempting to work this free, the string fell of the hook. Three weeks were spent on fishing for the string without complete success. The top of the fish is left at 3910 m.
    About ten m sandstone was encountered in top Lysing Formation (Late Cenomanian ? Turonian). The sandstone was cored and it contained hydrocarbons but none were produced during DST. The Garn Formation was encountered at 3980 m and a pore pressure considerably higher than expected was observed. Shows were recorded on the cores from the Lysing. Shows recorded in sandstone sequences throughout the Jurassic indicated residual hydrocarbons. Three cores were cut in the well: one from 3135 m to 3157 m in the Lysing to Lange Formations and two from 3972 m to 4008.5 m in the Melke to Garn Formations. The well was plugged and abandoned on 13 August 1985 as a dry well with shows.
    Testing
    One DST test was performed in the Lysing Formation between 3133 m to 3150 m. Only water was produced and the test indicated poor reservoir characteristics. Maximum temperature at 3095.62 m was 105.9°C

  • 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]
    370.00
    4457.00

  • 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
    3129.0
    3150.9
    [m ]
    2
    3972.0
    3980.1
    [m ]
    3
    3980.2
    4008.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    58.5
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3129-3133m
    Core photo at depth: 3134-3138m
    Core photo at depth: 3139-3143m
    Core photo at depth: 3144-3148m
    Core photo at depth: 3149-3150m
    3129-3133m
    3134-3138m
    3139-3143m
    3144-3148m
    3149-3150m
    Core photo at depth: 3972-3977m
    Core photo at depth: 3978-3980m
    Core photo at depth: 3980-3985m
    Core photo at depth: 3986-3991m
    Core photo at depth: 3992-3997m
    3972-3977m
    3978-3980m
    3980-3985m
    3986-3991m
    3992-3997m
    Core photo at depth: 3998-4003m
    Core photo at depth: 4004-4008m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3998-4003m
    4004-4008m

  • 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
    356.0
    36
    357.0
    0.00
    LOT
    SURF.COND.
    20
    622.0
    26
    680.0
    1.54
    LOT
    INTERM.
    13 3/8
    2089.0
    17 1/2
    2107.0
    1.79
    LOT
    INTERM.
    9 5/8
    3936.0
    12 1/4
    3955.0
    1.92
    LOT
    OPEN HOLE
    4457.0
    8 1/2
    4457.0
    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
    3133
    3150
    12.7
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    17.000
    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

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    270
    2087
    CBL VDL GR
    270
    2087
    CBL VDL GR
    275
    3905
    CST GR
    2207
    3505
    ISF LSS MSFL SP GR
    355
    638
    ISF LSS MSFL SP GR
    620
    2105
    ISF LSS MSFL SP GR
    2088
    3953
    ISF LSS MSFL SP GR
    3934
    4457
    LDL CNL GR
    620
    2106
    LDL CNL HGS GR
    2087
    3956
    LDL GR
    620
    2106
    MWD - GR RES DIR
    376
    4437
    NGS PL.B
    3650
    3956
    VSP
    630
    3905

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.76

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    4.80

  • 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
    32.29

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    680
    1.12
    6.0
    7.3
    WATERBASED
    10.04.1985
    680
    1.12
    6.0
    7.3
    WATER BASED
    10.04.1985
    1650
    1.21
    6.0
    7.0
    WATERBASED
    23.04.1985
    1650
    1.21
    6.0
    7.0
    WATER BASED
    23.04.1985
    2107
    1.50
    6.0
    7.0
    WATERBASED
    25.04.1985
    2107
    1.50
    6.0
    7.0
    WATER BASED
    25.04.1985
    3950
    1.73
    18.0
    6.7
    WATER BASED
    04.06.1985
    3950
    1.73
    18.0
    6.7
    WATERBASED
    04.06.1985
    3978
    1.79
    18.0
    7.0
    WATERBASED
    20.06.1985
    3978
    1.79
    18.0
    7.0
    WATER BASED
    20.06.1985
    4112
    1.79
    22.0
    7.7
    WATER BASED
    25.06.1985
    4112
    1.79
    22.0
    7.7
    WATERBASED
    25.06.1985

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1630.0
    [m]
    DC
    OD
    1990.0
    [m]
    DC
    STRAT
    2010.0
    [m]
    DC
    STRAT
    2020.0
    [m]
    DC
    STRAT
    2040.0
    [m]
    DC
    STRAT
    2050.0
    [m]
    DC
    STRAT
    2070.0
    [m]
    DC
    STRAT
    2080.0
    [m]
    DC
    STRAT
    2100.0
    [m]
    DC
    STRAT
    2110.0
    [m]
    DC
    STRAT
    2130.0
    [m]
    DC
    STRAT
    2140.0
    [m]
    DC
    STRAT
    2140.0
    [m]
    DC
    OD
    2160.0
    [m]
    DC
    STRAT
    2170.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    OD
    2190.0
    [m]
    DC
    STRAT
    2210.0
    [m]
    DC
    STRAT
    2220.0
    [m]
    DC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2250.0
    [m]
    DC
    STRAT
    2270.0
    [m]
    DC
    STRAT
    2280.0
    [m]
    DC
    STRAT
    2300.0
    [m]
    DC
    STRAT
    2310.0
    [m]
    DC
    STRAT
    2326.0
    [m]
    DC
    STRAT
    2340.0
    [m]
    DC
    STRAT
    2360.0
    [m]
    DC
    STRAT
    2375.0
    [m]
    SWC
    STRAT
    2381.0
    [m]
    DC
    STRAT
    2390.0
    [m]
    DC
    STRAT
    2405.0
    [m]
    DC
    STRAT
    2434.0
    [m]
    DC
    STRAT
    2449.0
    [m]
    DC
    STRAT
    2464.0
    [m]
    DC
    STRAT
    2481.5
    [m]
    SWC
    STRAT
    2482.0
    [m]
    DC
    STRAT
    2497.0
    [m]
    DC
    STRAT
    2509.0
    [m]
    DC
    STRAT
    2527.0
    [m]
    DC
    STRAT
    2539.0
    [m]
    DC
    STRAT
    2554.0
    [m]
    DC
    STRAT
    2569.0
    [m]
    DC
    STRAT
    2579.5
    [m]
    SWC
    STRAT
    2584.0
    [m]
    DC
    STRAT
    2599.0
    [m]
    DC
    STRAT
    2614.0
    [m]
    DC
    STRAT
    2629.0
    [m]
    DC
    STRAT
    2644.0
    [m]
    DC
    STRAT
    2659.0
    [m]
    DC
    STRAT
    2674.0
    [m]
    DC
    STRAT
    2679.5
    [m]
    SWC
    STRAT
    2689.0
    [m]
    DC
    STRAT
    2704.0
    [m]
    DC
    STRAT
    2734.0
    [m]
    DC
    STRAT
    2749.0
    [m]
    DC
    STRAT
    2764.0
    [m]
    DC
    STRAT
    2779.0
    [m]
    DC
    STRAT
    2780.0
    [m]
    SWC
    STRAT
    2794.0
    [m]
    DC
    STRAT
    2809.0
    [m]
    DC
    STRAT
    2824.0
    [m]
    DC
    STRAT
    2839.0
    [m]
    DC
    STRAT
    2853.0
    [m]
    DC
    STRAT
    2868.0
    [m]
    DC
    STRAT
    2879.5
    [m]
    SWC
    STRAT
    2884.0
    [m]
    DC
    STRAT
    2899.0
    [m]
    DC
    STRAT
    2914.0
    [m]
    DC
    STRAT
    2929.0
    [m]
    DC
    STRAT
    2934.5
    [m]
    SWC
    STRAT
    2944.0
    [m]
    DC
    STRAT
    2959.0
    [m]
    DC
    STRAT
    2974.0
    [m]
    DC
    STRAT
    2989.0
    [m]
    DC
    STRAT
    3004.0
    [m]
    DC
    STRAT
    3019.0
    [m]
    DC
    STRAT
    3034.0
    [m]
    DC
    STRAT
    3034.0
    [m]
    DC
    RRI
    3049.0
    [m]
    DC
    STRAT
    3052.0
    [m]
    DC
    RRI
    3064.0
    [m]
    DC
    STRAT
    3070.0
    [m]
    DC
    RRI
    3079.0
    [m]
    DC
    STRAT
    3084.5
    [m]
    SWC
    STRAT
    3094.0
    [m]
    DC
    STRAT
    3094.0
    [m]
    DC
    RRI
    3109.0
    [m]
    DC
    STRAT
    3114.5
    [m]
    SWC
    STRAT
    3124.0
    [m]
    DC
    STRAT
    3129.1
    [m]
    C
    STRAT
    3130.1
    [m]
    C
    SAGA
    3130.4
    [m]
    C
    SAGA
    3132.5
    [m]
    C
    STRAT
    3133.2
    [m]
    C
    STRAT
    3133.4
    [m]
    C
    SAGA
    3136.6
    [m]
    C
    STRAT
    3137.8
    [m]
    C
    SAGA
    3139.0
    [m]
    DC
    STRAT
    3139.7
    [m]
    C
    STRAT
    3141.0
    [m]
    C
    STRAT
    3143.2
    [m]
    C
    SAGA
    3143.4
    [m]
    C
    STRAT
    3143.7
    [m]
    C
    STRAT
    3144.3
    [m]
    C
    SAGA
    3146.4
    [m]
    C
    STRAT
    3146.8
    [m]
    C
    SAGA
    3148.1
    [m]
    C
    STRAT
    3149.2
    [m]
    C
    SAGA
    3150.0
    [m]
    C
    STRAT
    3150.9
    [m]
    C
    SAGA
    3154.0
    [m]
    DC
    STRAT
    3160.0
    [m]
    DC
    RRI
    3169.0
    [m]
    DC
    STRAT
    3181.0
    [m]
    DC
    RRI
    3184.0
    [m]
    DC
    STRAT
    3199.0
    [m]
    DC
    STRAT
    3204.5
    [m]
    SWC
    STRAT
    3214.0
    [m]
    DC
    STRAT
    3223.0
    [m]
    DC
    RRI
    3229.0
    [m]
    DC
    STRAT
    3244.0
    [m]
    DC
    STRAT
    3244.0
    [m]
    DC
    RRI
    3259.0
    [m]
    DC
    STRAT
    3264.5
    [m]
    SWC
    STRAT
    3274.0
    [m]
    DC
    STRAT
    3283.0
    [m]
    DC
    RRI
    3289.0
    [m]
    DC
    STRAT
    3301.0
    [m]
    DC
    RRI
    3304.0
    [m]
    DC
    STRAT
    3319.0
    [m]
    DC
    STRAT
    3319.0
    [m]
    DC
    RRI
    3334.0
    [m]
    DC
    STRAT
    3337.0
    [m]
    DC
    RRI
    3349.0
    [m]
    DC
    STRAT
    3354.5
    [m]
    SWC
    STRAT
    3364.0
    [m]
    DC
    STRAT
    3373.0
    [m]
    DC
    RRI
    3379.0
    [m]
    DC
    STRAT
    3391.0
    [m]
    DC
    RRI
    3394.0
    [m]
    DC
    STRAT
    3409.0
    [m]
    DC
    STRAT
    3409.0
    [m]
    DC
    RRI
    3424.0
    [m]
    DC
    STRAT
    3427.0
    [m]
    DC
    RRI
    3439.0
    [m]
    DC
    STRAT
    3444.5
    [m]
    SWC
    STRAT
    3454.0
    [m]
    DC
    STRAT
    3463.0
    [m]
    DC
    RRI
    3469.0
    [m]
    DC
    STRAT
    3484.0
    [m]
    DC
    STRAT
    3493.0
    [m]
    DC
    RRI
    3499.0
    [m]
    DC
    STRAT
    3504.5
    [m]
    SWC
    STRAT
    3514.0
    [m]
    DC
    STRAT
    3523.0
    [m]
    DC
    RRI
    3529.0
    [m]
    DC
    STRAT
    3541.0
    [m]
    DC
    RRI
    3544.0
    [m]
    DC
    STRAT
    3559.0
    [m]
    DC
    STRAT
    3559.0
    [m]
    DC
    RRI
    3574.0
    [m]
    DC
    STRAT
    3577.0
    [m]
    DC
    RRI
    3589.0
    [m]
    DC
    STRAT
    3595.0
    [m]
    DC
    RRI
    3604.0
    [m]
    DC
    STRAT
    3613.0
    [m]
    DC
    RRI
    3619.0
    [m]
    DC
    STRAT
    3631.0
    [m]
    DC
    RRI
    3634.0
    [m]
    DC
    STRAT
    3649.0
    [m]
    DC
    STRAT
    3649.0
    [m]
    DC
    RRI
    3664.0
    [m]
    DC
    RRI
    3667.0
    [m]
    DC
    RRI
    3679.0
    [m]
    DC
    STRAT
    3685.0
    [m]
    DC
    RRI
    3697.0
    [m]
    DC
    STRAT
    3703.0
    [m]
    DC
    RRI
    3709.0
    [m]
    DC
    STRAT
    3721.0
    [m]
    DC
    RRI
    3724.0
    [m]
    DC
    STRAT
    3736.0
    [m]
    DC
    STRAT
    3739.0
    [m]
    DC
    RRI
    3754.0
    [m]
    DC
    STRAT
    3757.0
    [m]
    DC
    RRI
    3769.0
    [m]
    DC
    STRAT
    3775.0
    [m]
    DC
    RRI
    3784.0
    [m]
    DC
    STRAT
    3793.0
    [m]
    DC
    RRI
    3799.0
    [m]
    DC
    STRAT
    3811.0
    [m]
    DC
    RRI
    3814.0
    [m]
    DC
    STRAT
    3820.0
    [m]
    DC
    RRI
    3829.0
    [m]
    DC
    STRAT
    3835.0
    [m]
    DC
    RRI
    3844.0
    [m]
    DC
    STRAT
    3847.0
    [m]
    DC
    RRI
    3859.0
    [m]
    DC
    STRAT
    3859.0
    [m]
    DC
    RRI
    3871.0
    [m]
    DC
    RRI
    3874.0
    [m]
    DC
    STRAT
    3889.0
    [m]
    DC
    STRAT
    3898.0
    [m]
    DC
    STRAT
    3934.0
    [m]
    DC
    STRAT
    3943.0
    [m]
    DC
    STRAT
    3964.0
    [m]
    DC
    STRAT
    3970.0
    [m]
    DC
    STRAT
    3972.1
    [m]
    C
    STRAT
    3972.2
    [m]
    C
    STRAT
    3972.6
    [m]
    C
    OD
    3973.1
    [m]
    C
    OD
    3974.1
    [m]
    C
    STRAT
    3974.5
    [m]
    C
    OD
    3975.2
    [m]
    C
    STRAT
    3975.7
    [m]
    C
    OD
    3976.1
    [m]
    C
    STRAT
    3977.0
    [m]
    C
    OD
    3977.0
    [m]
    C
    STRAT
    3977.6
    [m]
    C
    STRAT
    3983.0
    [m]
    C
    STRAT
    3988.4
    [m]
    C
    OD
    3993.0
    [m]
    C
    STRAT
    3997.9
    [m]
    C
    STRAT
    4012.0
    [m]
    DC
    STRAT
    4021.0
    [m]
    DC
    STRAT
    4030.0
    [m]
    DC
    STRAT
    4039.0
    [m]
    DC
    STRAT
    4048.0
    [m]
    DC
    STRAT
    4057.0
    [m]
    DC
    STRAT
    4066.0
    [m]
    DC
    STRAT
    4075.0
    [m]
    DC
    STRAT
    4084.0
    [m]
    DC
    STRAT
    4093.0
    [m]
    DC
    STRAT
    4102.0
    [m]
    DC
    STRAT
    4111.0
    [m]
    DC
    STRAT
    4120.0
    [m]
    DC
    STRAT
    4132.0
    [m]
    DC
    STRAT
    4138.0
    [m]
    DC
    STRAT
    4156.0
    [m]
    DC
    STRAT
    4165.0
    [m]
    DC
    STRAT
    4174.0
    [m]
    DC
    STRAT
    4183.0
    [m]
    DC
    STRAT
    4192.0
    [m]
    DC
    STRAT
    4201.0
    [m]
    DC
    STRAT
    4210.0
    [m]
    DC
    STRAT
    4219.0
    [m]
    DC
    STRAT
    4228.0
    [m]
    DC
    STRAT
    4237.0
    [m]
    DC
    STRAT
    4246.0
    [m]
    DC
    STRAT
    4255.0
    [m]
    DC
    STRAT
    4264.0
    [m]
    DC
    STRAT
    4273.0
    [m]
    DC
    STRAT
    4282.0
    [m]
    DC
    STRAT
    4291.0
    [m]
    DC
    STRAT
    4300.0
    [m]
    DC
    STRAT
    4309.0
    [m]
    DC
    STRAT
    4318.0
    [m]
    DC
    STRAT
    4327.0
    [m]
    DC
    STRAT
    4399.0
    [m]
    DC
    STRAT
    4408.0
    [m]
    DC
    STRAT
    4417.0
    [m]
    DC
    STRAT
    4426.0
    [m]
    DC
    STRAT
    4435.0
    [m]
    DC
    STRAT
    4444.0
    [m]
    DC
    STRAT
    4459.0
    [m]
    DC
    STRAT

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3129.35
    [m ]
    3136.35
    [m ]
    3138.35
    [m ]
    3139.35
    [m ]