Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
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15/2-1

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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.
    15/2-1
    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
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    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    15/2-1
    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.
    310-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.
    91
    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,
    26.11.1981
    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.
    24.02.1982
    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.
    24.02.1984
    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.
    01.08.2010
    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 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.
    109.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4600.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    8.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    132
    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.
    LATE PERMIAN
    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.
    ZECHSTEIN GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 45' 19.3'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 35' 40.58'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6513814.19
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    418684.57
    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.
    308

  • Wellbore history
    General
    Well 15/2-1 was drilled in the Vilje sub-basin in the Viking Graben in the North Sea, ca 1.5 km from the UK border. The objective of the well 15/2-1 was to test the Upper Jurassic, Middle Jurassic, and Triassic sandstone reservoirs northwest of and down dip of the salt diapir encountered in the well 15/5-3. The well was planned to be drilled ca 200 m into the Triassic with a total depth of ca 4525 m.
    Operations and results
    Wildcat well 15/2-1 was spudded with the semi-submersible installation Nortrym on 26 September 1981 and drilled to TD at 4600 m in the Late Permian Zechstein Group. No significant problems were encountered in the operations. The well was drilled with seawater and hi-vis pills down to 665 m and with Shaletrol polymer mud system from 665 m to 2750 m. At 2750 m the mud was converted to a dispersed mud system by adding lignosulphonate and this was used for the remaining well bore down to TD. There was 0 - 3% oil in the mud below 1168 m.
    The well penetrated a number of sandstone Formations in the Tertiary (Skade, Grid, Intra Balder sandstone, Heimdal, and Ty Formations). All these were entirely water wet. The Hugin Formation (4356 - 4493 m) consisted of massive very fine grained sandstones with beds of coal on top. The Sleipner Formation (4493 - 4554.5 m) had a 10 m thick coal layer on top underlain by siltstones grading occasionally to very fine sandstones, interbeds of sandstones, and stringers of coal. The well did not penetrate any Early Jurassic or Triassic rocks, but encountered evaporites of Permian age at 4554.5 m, unconformably underlying the Sleipner Formation.
    Good hydrocarbon shows were reported from both the Hugin and Sleipner Formations. However, wire line log evaluation and core analysis showed very poor reservoir parameters and no moveable hydrocarbons. Fluorescence and cut were observed also on limestone and shale cuttings in the Tor Formation at 2800 - 2835 and in the Early Cretaceous at 3815 - 3922 m
    Three cores were cut from 4365 to 4405 m in the Hugin Formation. The RFT tool was run in the Hugin Formation. The formation proved to be tight and no wire line fluid samples were taken.
    The well was permanently abandoned on 24 February 1982 as a dry well with shows.
    Testing
    No drill stem test was performed.

  • 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]
    200.00
    4600.00

  • 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
    4368.0
    4369.8
    [m ]
    2
    4369.8
    4390.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    22.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 4365-4368m
    Core photo at depth: 4368-4371m
    Core photo at depth: 4375-4378m
    Core photo at depth: 4379-4384m
    Core photo at depth: 4384-4389m
    4365-4368m
    4368-4371m
    4375-4378m
    4379-4384m
    4384-4389m

  • 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
    196.0
    36
    196.0
    0.00
    LOT
    SURF.COND.
    20
    653.0
    26
    655.0
    1.72
    LOT
    INTERM.
    13 3/8
    2737.0
    17 1/2
    2750.0
    1.71
    LOT
    INTERM.
    9 5/8
    3770.0
    12 1/4
    3786.0
    1.99
    LOT
    OPEN HOLE
    4600.0
    8 3/8
    4600.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    400
    3763
    CST
    1429
    2748
    CST
    1429
    2705
    CST
    2764
    3520
    CST
    3537
    3781
    CST
    3789
    4114
    CST
    3844
    4516
    CST
    4131
    4354
    CST
    4357
    4554
    FDC CNL
    653
    4600
    HDT
    2736
    4565
    ISF SONIC
    134
    4599
    RFT
    4365
    4417
    RFT
    4416
    4419

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.88

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.41
    pdf
    2.27

  • 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
    3.37
    pdf
    35.90

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    250
    1.08
    36.0
    waterbased
    650
    1.11
    32.0
    waterbased
    1560
    1.11
    65.0
    waterbased
    2180
    1.20
    65.0
    waterbased
    2840
    1.23
    65.0
    waterbased
    3160
    1.25
    65.0
    waterbased
    3840
    1.75
    67.0
    waterbased
    4150
    1.89
    59.0
    waterbased
    4580
    1.88
    60.0
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2060.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2150.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2180.0
    [m]
    DC
    RRI
    2210.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2590.0
    [m]
    DC
    RRI
    2610.0
    [m]
    DC
    RRI
    2630.0
    [m]
    DC
    RRI
    2640.0
    [m]
    DC
    RRI
    2650.0
    [m]
    DC
    RRI
    3650.0
    [m]
    SWC
    RRI
    3660.5
    [m]
    SWC
    RRI
    3669.0
    [m]
    SWC
    RRI
    3690.0
    [m]
    SWC
    RRI
    3705.0
    [m]
    SWC
    RRI
    3720.0
    [m]
    SWC
    RRI
    3736.0
    [m]
    SWC
    RRI
    3741.0
    [m]
    SWC
    RRI
    3750.0
    [m]
    SWC
    RRI
    3765.5
    [m]
    SWC
    RRI
    3779.0
    [m]
    SWC
    RRI
    3781.0
    [m]
    SWC
    RRI
    3839.0
    [m]
    SWC
    RRI
    3877.0
    [m]
    SWC
    RRI
    3880.0
    [m]
    SWC
    RRI
    3908.5
    [m]
    SWC
    RRI
    3927.0
    [m]
    SWC
    RRI
    3937.5
    [m]
    SWC
    RRI
    3948.5
    [m]
    SWC
    RRI
    3960.0
    [m]
    SWC
    RRI
    3974.0
    [m]
    SWC
    RRI
    4016.5
    [m]
    SWC
    RRI
    4030.5
    [m]
    SWC
    RRI
    4055.0
    [m]
    SWC
    RRI
    4089.5
    [m]
    SWC
    RRI
    4114.5
    [m]
    SWC
    RRI
    4131.0
    [m]
    SWC
    RRI
    4157.0
    [m]
    SWC
    RRI
    4166.0
    [m]
    SWC
    RRI
    4180.0
    [m]
    SWC
    RRI
    4198.5
    [m]
    SWC
    RRI
    4218.0
    [m]
    SWC
    RRI
    4234.5
    [m]
    SWC
    RRI
    4242.5
    [m]
    SWC
    RRI
    4262.0
    [m]
    SWC
    RRI
    4280.0
    [m]
    SWC
    RRI
    4288.0
    [m]
    SWC
    RRI
    4306.0
    [m]
    SWC
    RRI
    4311.0
    [m]
    SWC
    RRI
    4317.0
    [m]
    SWC
    RRI
    4325.0
    [m]
    SWC
    RRI
    4336.5
    [m]
    SWC
    RRI
    4341.5
    [m]
    SWC
    RRI
    4352.0
    [m]
    SWC
    RRI
    4354.0
    [m]
    SWC
    RRI
    4357.0
    [m]
    SWC
    RRI
    4364.5
    [m]
    SWC
    RRI
    4365.3
    [m]
    C
    WESTLAB
    4365.8
    [m]
    C
    RRI
    4368.8
    [m]
    C
    WESTLAB
    4370.4
    [m]
    C
    WESTLA
    4372.3
    [m]
    C
    WESTLA
    4375.3
    [m]
    C
    WESTLA
    4375.9
    [m]
    C
    RRI
    4378.1
    [m]
    C
    WESTLAB
    4381.9
    [m]
    C
    WESTLA
    4386.0
    [m]
    C
    WESTLA
    4387.7
    [m]
    C
    WESTLA
    4388.7
    [m]
    C
    WESTLA
    4389.7
    [m]
    C
    RRI
    4389.9
    [m]
    C
    WESTLAB
    4390.4
    [m]
    C
    RRI
    4392.0
    [m]
    C
    RRI
    4396.0
    [m]
    C
    RRI
    4397.5
    [m]
    C
    RRI
    4399.7
    [m]
    C
    RRI
    4399.8
    [m]
    C
    WESTLAB
    4405.0
    [m]
    C
    RRI
    4405.0
    [m]
    SWC
    RRI
    4424.0
    [m]
    SWC
    RRI
    4446.0
    [m]
    SWC
    RRI
    4481.0
    [m]
    SWC
    RRI
    4494.5
    [m]
    SWC
    RRI
    4535.0
    [m]
    SWC
    RRI
    4548.0
    [m]
    SWC
    RRI
    4554.0
    [m]
    SWC
    RRI