Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.12.2024 - 01:25
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7119/12-3

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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.
    7119/12-3
    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.
    BARENTS 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.
    7119/12-3
    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.
    376-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.
    116
    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,
    20.05.1983
    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.
    12.09.1983
    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.
    12.09.1985
    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.
    11.02.2005
    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/CONDENSATE
    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.
    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.
    STØ FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    29.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    211.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3314.0
    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).
    3308.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    136
    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.
    NORDMELA FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    71° 14' 20.18'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    19° 44' 37.92'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7904727.31
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    454909.86
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    34
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    17

  • Wellbore history
    General
    The primary objective of wildcat 7119/12-3 was to test possible hydrocarbon accumulations in sandstones of Middle to Lower Jurassic age. Gas and condensate were discovered in the sandstone sequences. Planned TD was 3765 m.
    Operations and results
    Exploration well 7119/12-3 was spudded with the semi-submersible installation Dyvi Delta on 20 may 1982 and drilled to TD at 3314 m in the Early Jurassic Nordmela Formation. A total of 121 days was spent on this well including testing and a 9.5 days seamen's strike. The time estimate was 106 days. No major problems occurred due to drilling. The well was drilled using spud mud down to 303 m, with gel/seawater from 303 m to 716 m, with gypsum/polymer from 716 m to 1618 m, and with gel/lignosulphonate from 1618 m to TD.
    Hydrocarbon accumulations were discovered in sandstone sequences between 3144 - 3285 m in the Stø Formation. From log evaluation the interval contained 118 m net sand. The gas/water contact at 3285 m is based on the log evaluation. Due to very tight and hard formation only two RFT pressure points were obtained out of 16 attempts (seal failures). Organic geochemical analyses found only poor source rock potential in the well. Shales in the Late Jurassic Hekkingen Formation from 3026 m to 3107 m had high TOC levels in the range 3% to 9%. However, with Hydrogen Indexes only in the range 30 - 40 mg HC/g TOC in non-caved, high-TOC samples, these shales are gas prone, and can not produce any significant quantities of liquid hydrocarbons. The well is immature down to ca 2300 m and reaches oil window maturity at ca 3000 m. Three cores were cut in the sandstones of the Middle to Early Jurassic Stø Formation. The two first were cut in the interval 3145 m to 3154.85 m with 100 % recovery. The third was cut from 3250 m to 3267 m with 97 % recovery. One RFT segregated sample was taken at 3187 m. The 2 3/4 -gallon chamber was bled off on the rig. It had an opening pressure of 38.9 bar and contained 0.226 m3 of gas and 9.5 1 of mud filtrate with a condensate film on the top of the filtrate. The 1-gallon chamber was drained onshore and had an opening pressure of 54 bar at 17°C. It contained 22.2 1 of gas and 3.525 1 mud filtrate.
    The well was permanently abandoned on 12 September 1983 as a gas/condensate discovery.
    Testing
    One DST was performed. The interval from 3185 m to 3195 m in the Stø Formation was perforated and production tested. The test flowed 956 900 Sm3 /day of gas with 15.2 Sm3 /day of condensate through a 64/64" choke. The gas contained 12.4 % CO2. The permeability of the tested zone was estimated to 17.42 mD with an average porosity of 5.3 % and an average water saturation of 28.9 %. After the DST three runs with cased hole RFT was performed. The result from these was bad due to tight formation or sealing failures.

  • 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]
    310.00
    3315.00

  • 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
    3145.0
    3148.3
    [m ]
    2
    3148.3
    3154.9
    [m ]
    3
    3250.0
    3266.5
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    26.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3145-3148m
    Core photo at depth: 3148-3154m
    Core photo at depth: 3256-3262m
    Core photo at depth: 3250-3256m
    Core photo at depth: 3262-3266m
    3145-3148m
    3148-3154m
    3256-3262m
    3250-3256m
    3262-3266m

  • 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
    3185.00
    3195.00
    03.09.1983 - 13:15
    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
    302.0
    36
    303.5
    0.00
    LOT
    SURF.COND.
    20
    700.0
    26
    716.0
    1.76
    LOT
    INTERM.
    13 3/8
    1603.0
    17 1/2
    1618.0
    1.90
    LOT
    INTERM.
    9 5/8
    3135.0
    12 1/4
    3140.0
    2.06
    LOT
    LINER
    7
    3314.0
    8 1/2
    3314.0
    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
    3185
    3195
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    17
    957000
    0.797
    0.722

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    450
    1603
    CBL VDL
    1000
    3136
    CBL VDL
    2800
    3234
    CST
    700
    1618
    CST
    1629
    3118
    CST
    2293
    2790
    CST
    2815
    3135
    CST
    3165
    3307
    DLL GR
    3136
    3315
    DLL GR
    3136
    3315
    HDT
    1603
    3144
    ISF BHC GR SP CAL
    240
    1617
    ISF BHC MSFL GR SP CAL
    1603
    3315
    LDL CNL GR
    302
    709
    LDL CNL GR
    3136
    3315
    LDL GR
    700
    3142
    RFT
    3147
    3283
    SHDT
    3136
    3315
    VELOCITY
    840
    3314

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.52

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    2.69

  • 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
    15.64
    pdf
    1.50

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    716
    1.25
    45.0
    36.0
    spud mud
    1510
    1.15
    50.0
    25.0
    water based
    1860
    1.35
    51.0
    13.0
    water based
    2372
    1.47
    52.0
    18.0
    water based
    2800
    1.65
    51.0
    15.0
    water based
    3005
    1.65
    56.0
    18.0
    water based
    3144
    1.72
    60.0
    14.0
    water based

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    310.0
    [m]
    DC
    RRI
    330.0
    [m]
    DC
    RRI
    350.0
    [m]
    DC
    RRI
    370.0
    [m]
    DC
    RRI
    390.0
    [m]
    DC
    RRI
    410.0
    [m]
    DC
    RRI
    430.0
    [m]
    DC
    RRI
    450.0
    [m]
    DC
    RRI
    470.0
    [m]
    DC
    RRI
    490.0
    [m]
    DC
    RRI
    510.0
    [m]
    DC
    RRI
    530.0
    [m]
    DC
    RRI
    550.0
    [m]
    DC
    RRI
    570.0
    [m]
    DC
    RRI
    590.0
    [m]
    DC
    RRI
    610.0
    [m]
    DC
    RRI
    630.0
    [m]
    DC
    RRI
    650.0
    [m]
    DC
    RRI
    670.0
    [m]
    DC
    RRI
    690.0
    [m]
    DC
    RRI
    710.0
    [m]
    DC
    RRI
    730.0
    [m]
    DC
    RRI
    750.0
    [m]
    SWC
    RRI
    770.0
    [m]
    DC
    RRI
    790.0
    [m]
    DC
    RRI
    810.0
    [m]
    DC
    RRI
    817.0
    [m]
    SWC
    RRI
    830.0
    [m]
    DC
    RRI
    850.0
    [m]
    DC
    RRI
    870.0
    [m]
    DC
    RRI
    890.0
    [m]
    SWC
    RRI
    915.0
    [m]
    SWC
    RRI
    930.0
    [m]
    DC
    RRI
    945.0
    [m]
    SWC
    RRI
    960.0
    [m]
    DC
    RRI
    975.0
    [m]
    DC
    RRI
    990.0
    [m]
    DC
    RRI
    1005.0
    [m]
    DC
    RRI
    1016.0
    [m]
    SWC
    RRI
    1030.0
    [m]
    DC
    RRI
    1045.0
    [m]
    DC
    RRI
    1060.0
    [m]
    DC
    RRI
    1070.0
    [m]
    DC
    RRI
    1086.0
    [m]
    SWC
    RRI
    1100.0
    [m]
    DC
    RRI
    1130.0
    [m]
    DC
    RRI
    1145.0
    [m]
    DC
    RRI
    1180.0
    [m]
    DC
    RRI
    1195.0
    [m]
    DC
    RRI
    1205.0
    [m]
    DC
    RRI
    1212.0
    [m]
    SWC
    RRI
    1225.0
    [m]
    DC
    RRI
    1240.0
    [m]
    DC
    RRI
    1255.0
    [m]
    DC
    RRI
    1270.0
    [m]
    DC
    RRI
    1285.0
    [m]
    DC
    RRI
    1295.0
    [m]
    DC
    RRI
    1309.0
    [m]
    SWC
    RRI
    1325.0
    [m]
    DC
    RRI
    1340.0
    [m]
    DC
    RRI
    1355.0
    [m]
    DC
    RRI
    1363.0
    [m]
    SWC
    RRI
    1380.0
    [m]
    DC
    RRI
    1395.0
    [m]
    DC
    RRI
    1410.0
    [m]
    DC
    RRI
    1425.0
    [m]
    DC
    RRI
    1441.0
    [m]
    SWC
    RRI
    1455.0
    [m]
    DC
    RRI
    1470.0
    [m]
    DC
    RRI
    1495.0
    [m]
    DC
    RRI
    1495.0
    [m]
    SWC
    RRI
    1510.0
    [m]
    DC
    RRI
    1525.0
    [m]
    DC
    RRI
    1540.0
    [m]
    DC
    RRI
    1555.0
    [m]
    DC
    RRI
    1575.0
    [m]
    SWC
    RRI
    1595.0
    [m]
    DC
    RRI
    1600.0
    [m]
    DC
    RRI
    1615.0
    [m]
    DC
    RRI
    1625.0
    [m]
    DC
    RRI
    1630.0
    [m]
    DC
    RRI
    1645.0
    [m]
    DC
    RRI
    1660.0
    [m]
    DC
    RRI
    1675.0
    [m]
    DC
    RRI
    1690.0
    [m]
    DC
    RRI
    1695.0
    [m]
    DC
    RRI
    1705.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1735.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1765.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1795.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1825.0
    [m]
    DC
    RRI
    1835.0
    [m]
    SWC
    RRI
    1840.0
    [m]
    DC
    RRI
    1855.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1885.0
    [m]
    DC
    RRI
    1895.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1915.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1945.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1975.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    1995.0
    [m]
    DC
    RRI
    2005.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2035.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2065.0
    [m]
    DC
    RRI
    2080.0
    [m]
    DC
    RRI
    2095.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2125.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2155.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2185.0
    [m]
    DC
    RRI
    2195.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2208.0
    [m]
    SWC
    RRI
    2215.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2245.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2260.0
    [m]
    SWC
    RRI
    2275.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2293.5
    [m]
    SWC
    RRI
    2297.5
    [m]
    SWC
    RRI
    2305.0
    [m]
    DC
    RRI
    2320.0
    [m]
    DC
    RRI
    2335.0
    [m]
    DC
    RRI
    2348.0
    [m]
    SWC
    RRI
    2350.0
    [m]
    DC
    RRI
    2365.0
    [m]
    DC
    RRI
    2380.0
    [m]
    DC
    RRI
    2395.0
    [m]
    DC
    RRI
    2397.5
    [m]
    SWC
    RRI
    2400.0
    [m]
    SWC
    RRI
    2410.0
    [m]
    DC
    RRI
    2425.0
    [m]
    DC
    RRI
    2440.0
    [m]
    DC
    RRI
    2450.0
    [m]
    SWC
    RRI
    2450.0
    [m]
    DC
    RRI
    2455.0
    [m]
    DC
    RRI
    2470.0
    [m]
    DC
    RRI
    2480.0
    [m]
    DC
    RRI
    2489.0
    [m]
    SWC
    RRI
    2495.0
    [m]
    DC
    RRI
    2510.0
    [m]
    DC
    RRI
    2525.0
    [m]
    DC
    RRI
    2542.5
    [m]
    SWC
    RRI
    2550.0
    [m]
    DC
    RRI
    2555.0
    [m]
    DC
    RRI
    2570.0
    [m]
    DC
    RRI
    2591.0
    [m]
    SWC
    RRI
    2600.0
    [m]
    DC
    RRI
    2615.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2645.0
    [m]
    DC
    RRI
    2650.0
    [m]
    SWC
    RRI
    2650.0
    [m]
    DC
    RRI
    2660.0
    [m]
    DC
    RRI
    2687.0
    [m]
    SWC
    RRI
    2705.0
    [m]
    DC
    RRI
    2712.0
    [m]
    SWC
    RRI
    2735.0
    [m]
    DC
    RRI
    2750.0
    [m]
    DC
    RRI
    2755.0
    [m]
    SWC
    RRI
    2765.0
    [m]
    DC
    RRI
    2780.0
    [m]
    DC
    RRI
    2795.0
    [m]
    DC
    RRI
    2810.0
    [m]
    DC
    RRI
    2825.0
    [m]
    DC
    RRI
    2850.0
    [m]
    DC
    RRI
    2855.0
    [m]
    DC
    RRI
    2870.0
    [m]
    DC
    RRI
    2900.0
    [m]
    DC
    RRI
    2915.0
    [m]
    DC
    RRI
    2930.0
    [m]
    DC
    RRI
    2950.0
    [m]
    DC
    RRI
    2955.0
    [m]
    DC
    RRI
    2960.0
    [m]
    DC
    RRI
    2965.0
    [m]
    DC
    RRI
    2975.0
    [m]
    DC
    RRI
    2980.0
    [m]
    DC
    RRI
    3005.0
    [m]
    DC
    RRI
    3035.0
    [m]
    DC
    RRI
    3050.0
    [m]
    DC
    RRI
    3080.0
    [m]
    DC
    RRI
    3102.0
    [m]
    SWC
    RRI
    3110.0
    [m]
    DC
    RRI
    3123.0
    [m]
    SWC
    RRI
    3140.0
    [m]
    DC
    RRI
    3155.0
    [m]
    DC
    RRI
    3170.0
    [m]
    DC
    RRI
    3200.0
    [m]
    DC
    RRI
    3300.0
    [m]
    DC
    RRI
    3314.0
    [m]
    C
    RRI

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3265.60
    [m ]
    3253.85
    [m ]
    3154.80
    [m ]
    3147.90
    [m ]