Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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27.11.2024 - 01:27
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15/9-3

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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.
    15/9-3
    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).
    APPRAISAL
    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
    Factmaps in new window
    Main area
    Name of the area on the Norwegian Continental Shelf where the wellbore is located. Legal values: BARENTS SEA, NORWEGIAN SEA, NORTH SEA.
    NORTH SEA
    Field
    Name of the field the wellbore is related to.
    Discovery
    Name of the discovery the wellbore is related to.
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    15/9-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Line 753-411.SP 272
    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.
    206-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.
    108
    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,
    17.12.1978
    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.
    03.04.1979
    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.
    03.04.1981
    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.
    08.04.2015
    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.
    APPRAISAL
    Reentry
    Status whether the wellbore has been re-entered (YES) or not (NO). Re-entered wellbores are not included in the count when wellbores are presented in statistical overviews.
    NO
    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.
    115.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3796.0
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    107
    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.
    TRIASSIC
    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.
    SKAGERRAK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 29' 10.04'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 41' 38.46'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6483722.00
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    423852.54
    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.
    324

  • Wellbore history
    General
    Well was drilled on the northwestern part of the Sleipner Vest structure in the Viking Graben of the North Sea. The objective was to test hydrocarbons in the “Alpha structure” of the Sleipner field. The target was Middle Jurassic sandstones.
    Operations and results
    Appraisal well 15/9-3 was spudded with the semi-submersible installation Ross Rig on 17 December 1978 and drilled to TD at 3796 m in the Triassic Skagerrak Formation. Many problems were encountered in the operations. When drilling the 26" interval, the circulation was lost several times. Pumping lost circulation material pills and cement into the formation solved this. The main problem arose when drilling the 8 1/2” interval.  At 3375 m on top of Upper Jurassic, an abnormally pressured impermeable zone was penetrated. Due to a series of technical problems that followed this incident, the well was finally plugged back and sidetracked from 1213 m. Furthermore, the well was drilled in the wintertime and the cold was quite severe. Because of this, the hydraulic control system for the BOP stack froze on one occasion. Functional problems with the BOP pods were experienced, consequently, the time and cost estimates, were seriously exceeded. The well was drilled with spud mud down to 402 m, with gel/lignosulphonate from 402 m to 2680 m and with gel/lignosulphonate/lignite mud from 2680 m to TD.
    The Middle Jurassic Vestland Group, top Hugin Formation, was encountered at 3498 m. Well 15/9-3 proved very poor reservoir qualities in these strata and the well was hence not production tested. A cluster of RFT pressure data points suggested a light hydrocarbon gradient of 0.11 - 0.25 psi/ft. between 3600 m and 3612 m. Between 3650 m and 3682 m a good "heavier" hydrocarbon gradient of 0.35 psi/ft. was established. This indicates a hydrocarbon/water contact approximately at 3682 m. Very weak spotted shows were described over this section and down to 3709 m.
    Four cores were cut from the interval 3511 to 3580 m in the Hugin Formation. RFT fluid-sampling chambers recovered six samples, all containing mud filtrate with minor amounts of gas.
    The well was permanently abandoned on 3 April 1981 and was classified as dry 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
    3795.00

  • 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
    3511.0
    3528.7
    [m ]
    2
    3529.0
    3546.7
    [m ]
    3
    3547.0
    3565.1
    [m ]
    4
    3565.1
    3579.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    68.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3511-3513m
    Core photo at depth: 3513-3516m
    Core photo at depth: 3516-3519m
    Core photo at depth: 3519-3521m
    Core photo at depth: 3521-3524m
    3511-3513m
    3513-3516m
    3516-3519m
    3519-3521m
    3521-3524m
    Core photo at depth: 3524-3527m
    Core photo at depth: 3527-3528m
    Core photo at depth: 3529-3531m
    Core photo at depth: 3521-3534m
    Core photo at depth: 3534-3537m
    3524-3527m
    3527-3528m
    3529-3531m
    3521-3534m
    3534-3537m
    Core photo at depth: 3537-3539m
    Core photo at depth: 3539-3542m
    Core photo at depth: 3542-3545m
    Core photo at depth: 3545-3546m
    Core photo at depth: 3547-3549m
    3537-3539m
    3539-3542m
    3542-3545m
    3545-3546m
    3547-3549m
    Core photo at depth: 3549-3552m
    Core photo at depth: 3552-3551m
    Core photo at depth: 3555-3557m
    Core photo at depth: 3557-3560m
    Core photo at depth: 3560-3563m
    3549-3552m
    3552-3551m
    3555-3557m
    3557-3560m
    3560-3563m
    Core photo at depth: 3563-3565m
    Core photo at depth: 3565-3567m
    Core photo at depth: 3567-3570m
    Core photo at depth: 3570-3573m
    Core photo at depth: 3573-3575m
    3563-3565m
    3565-3567m
    3567-3570m
    3570-3573m
    3573-3575m
    Core photo at depth: 3575-3578m
    Core photo at depth: 3578-3579m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3575-3578m
    3578-3579m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2223.0
    [m]
    DC
    RRI
    2238.0
    [m]
    DC
    RRI
    2253.0
    [m]
    DC
    RRI
    2283.0
    [m]
    DC
    RRI
    2301.0
    [m]
    DC
    RRI
    2319.0
    [m]
    DC
    RRI
    2331.0
    [m]
    DC
    RRI
    2349.0
    [m]
    DC
    RRI
    2367.0
    [m]
    DC
    RRI
    2379.0
    [m]
    DC
    RRI
    2421.0
    [m]
    DC
    RRI
    2433.0
    [m]
    DC
    RRI
    2553.0
    [m]
    DC
    RRI
    2559.0
    [m]
    DC
    RRI
    2571.0
    [m]
    DC
    RRI
    2583.0
    [m]
    DC
    RRI
    2595.0
    [m]
    DC
    RRI
    2601.0
    [m]
    DC
    RRI
    2613.0
    [m]
    DC
    RRI
    2622.0
    [m]
    DC
    RRI
    2631.0
    [m]
    DC
    RRI
    2763.6
    [m]
    C
    OD
    2767.2
    [m]
    C
    OD
    2770.7
    [m]
    C
    OD
    2772.0
    [m]
    C
    OD
    2773.5
    [m]
    C
    OD
    2774.0
    [m]
    C
    OD
    2781.9
    [m]
    C
    OD
    2784.3
    [m]
    C
    OD
    2789.3
    [m]
    C
    OD
    2791.3
    [m]
    C
    OD
    2791.8
    [m]
    C
    OD
    3299.0
    [m]
    DC
    3329.0
    [m]
    DC
    3359.0
    [m]
    DC
    3389.0
    [m]
    DC
    3419.0
    [m]
    DC
    3449.0
    [m]
    DC
    3479.0
    [m]
    DC
    3479.0
    [m]
    DC
    HRS
    3488.0
    [m]
    DC
    HRS
    3497.0
    [m]
    DC
    HRS
    3509.0
    [m]
    DC
    HRS
    3509.0
    [m]
    DC
    3509.0
    [m]
    DC
    HRS
    3511.0
    [m]
    SWC
    RRI
    3511.1
    [m]
    C
    3511.9
    [m]
    C
    3512.4
    [m]
    C
    HRS
    3517.0
    [m]
    C
    3518.8
    [m]
    C
    HRS
    3521.0
    [m]
    C
    3525.0
    [m]
    C
    HRS
    3528.0
    [m]
    DC
    3532.0
    [m]
    DC
    3534.9
    [m]
    C
    HRS
    3536.0
    [m]
    DC
    3542.0
    [m]
    DC
    3544.8
    [m]
    C
    HRS
    3547.5
    [m]
    C
    3549.0
    [m]
    C
    3549.2
    [m]
    C
    HRS
    3553.7
    [m]
    C
    3557.7
    [m]
    C
    HRS
    3563.4
    [m]
    C
    3565.0
    [m]
    C
    HRS
    3569.4
    [m]
    C
    3573.5
    [m]
    C
    3575.6
    [m]
    C
    HRS
    3579.5
    [m]
    C
    HRS
    3579.5
    [m]
    C
    3587.0
    [m]
    DC
    HRS
    3596.0
    [m]
    DC
    HRS
    3599.0
    [m]
    DC
    3608.0
    [m]
    DC
    HRS
    3623.0
    [m]
    DC
    HRS
    3629.0
    [m]
    DC
    3632.0
    [m]
    DC
    HRS
    3641.0
    [m]
    DC
    HRS
    3650.0
    [m]
    DC
    HRS
    3659.0
    [m]
    DC
    HRS
    3659.0
    [m]
    DC
    3667.0
    [m]
    DC
    HRS
    3682.0
    [m]
    DC
    HRS
    3688.0
    [m]
    DC
    3691.0
    [m]
    DC
    HRS
    3706.0
    [m]
    DC
    HRS
    3718.0
    [m]
    DC
    3748.0
    [m]
    DC
    3780.0
    [m]
    DC
    3792.0
    [m]
    DC

  • Lithostratigraphy

  • 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
    29.40

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    375
    2863
    DLL
    3435
    3781
    FDC CAL GR
    402
    3793
    HDT
    2863
    3792
    ISF SON GR SP
    139
    3797
    RFT
    3439
    3795
    VELOCITY
    570
    3730

  • 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
    177.0
    36
    178.0
    0.00
    LOT
    SURF.COND.
    20
    402.0
    26
    416.0
    1.41
    LOT
    INTERM.
    13 3/8
    1178.0
    17 1/2
    1195.0
    1.90
    LOT
    INTERM.
    9 5/8
    2866.0
    12 1/4
    2880.0
    1.69
    LOT
    LINER
    7
    3439.0
    8 1/2
    3440.0
    2.03
    LOT
    OPEN HOLE
    3796.0
    6 1/2
    3796.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    416
    1.06
    48.0
    waterbased
    815
    1.15
    46.0
    waterbased
    1300
    1.23
    45.0
    waterbased
    1860
    1.28
    53.0
    waterbased
    2813
    1.20
    44.0
    waterbased
    3344
    1.45
    54.0
    waterbased
    3492
    1.36
    49.0
    waterbased
    3655
    1.38
    52.0
    waterbased