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

15/9-10

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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.
    15/9-10
    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.
    15/9-10
    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.
    302-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.
    54
    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,
    15.09.1981
    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.
    07.11.1981
    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.
    07.11.1983
    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.
    DRY
    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.
    98.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3289.0
    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).
    3288.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    100
    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.
    SMITH BANK FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 19' 42.92'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 46' 20.61'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6466097.13
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    428101.86
    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.
    69

  • Wellbore history
    General
    Wildcat well is located between the Sleipner Vest and Sleipner Øst Fields. The well was designed to test possible hydrocarbon accumulations in the Upper Middle Jurassic sands and secondary test Heimdal Formation Sand of Paleocene age.
    Operations and results
    Wildcat well 15/9-10 was spudded with the semi-submersible installation Neptuno Nordraug on 15 September 1981 and drilled to TD at 3289 m in the Triassic Smith Bank Formation. Drilling the 26" hole section complete loss of returns occurred at 186 m and a cement plug was set. Drilling out of the cement returns were again lost, at 178 m, requiring a further cement plug. Total losses due to this loss zone were well in excess of 10 000 bbls. After this operations went without significant problems. The well was drilled with seawater and hi-vis pills down to 172 m. The next section, the 26" section, was drilled down to 472 m with seawater/bentonite and quantities of Mica Fine, Nutplug, Kwikseal, and other additives. From 472 m to TD m the well was drilled with polymer/Drispac.
    The well encountered Tertiary sands in the Utsira Formation at 884 - 1102 m, Grid Formation at 2049 - 2079 m, Heimdal and Ty Formations at 2547 m to 2667 m. An RFT run in the Heimdal sand indicated a water gradient, 1.02 g/cm3. The primary target Jurassic sandstones was encountered at 3070 m in the Hugin and Sleipner Formations. Some shows were recorded in the Hugin Formation, but from the logs the formations were all water-wet. Possible source rocks were encountered in a comparatively thick and marly Blodøks Formation from 2871 m to 2924 m, and in the Late Jurassic Draupne and Heather Formations from 3004 m to 3070 m. Four conventional cores were cut. Core 1 was cut from 3061 m to 3062.4 m in the Heather Formation, core 2 was cut from 3082 m to 3100 m in the Hugin Formation, and cores 3 and 4 were cut from 3137 m to 3171 m in the Sleipner Formation. No fluid sample was taken.
    The well was permanently abandoned as dry with minor shows on 7 November 1981.
    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]
    180.00
    3285.00

  • 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
    3061.0
    3062.4
    [m ]
    2
    3082.0
    3101.0
    [m ]
    3
    3137.0
    3151.8
    [m ]
    4
    3153.0
    3171.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    53.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3061-3062m
    Core photo at depth: 3061-3062m
    Core photo at depth: 3082-3087m
    Core photo at depth: 3087-3092m
    Core photo at depth: 3092-3097m
    3061-3062m
    3061-3062m
    3082-3087m
    3087-3092m
    3092-3097m
    Core photo at depth: 3087-3092m
    Core photo at depth: 3092-3097m
    Core photo at depth: 3097-3101m
    Core photo at depth: 3137-3142m
    Core photo at depth: 3142-3147m
    3087-3092m
    3092-3097m
    3097-3101m
    3137-3142m
    3142-3147m
    Core photo at depth: 3147-3151m
    Core photo at depth: 3153-3158m
    Core photo at depth: 3158-3163m
    Core photo at depth: 3153-3158m
    Core photo at depth: 3158-3163m
    3147-3151m
    3153-3158m
    3158-3163m
    3153-3158m
    3158-3163m
    Core photo at depth: 3163-3168m
    Core photo at depth: 3168-3171m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3163-3168m
    3168-3171m

  • 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
    0.00
    0.00
    27.09.1993 - 19:00
    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
    172.0
    36
    173.0
    0.00
    LOT
    SURF.COND.
    20
    472.0
    26
    485.0
    1.75
    LOT
    INTERM.
    13 3/8
    1166.0
    17 1/2
    1178.0
    1.65
    LOT
    INTERM.
    9 5/8
    2706.0
    12 1/4
    2719.0
    1.78
    LOT
    OPEN HOLE
    3289.0
    8 1/2
    3289.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    119
    1420
    CBL VDL GR
    225
    1166
    CBL VDL GR
    698
    2695
    CST
    2342
    2675
    CYBERBOND
    225
    1166
    CYBERBOND
    698
    2695
    CYBERDIP
    2705
    3290
    CYBERLOOK
    3130
    3291
    FDC CNL GR
    2705
    3290
    FDC GR
    471
    2718
    GEODIP
    3125
    3250
    HDT
    2705
    3290
    ISF BHC GR
    172
    3289
    RFT
    2501
    2659
    VELOCITY
    580
    3280

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.53

  • 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
    16.17
    pdf
    1.86
    pdf
    0.11
    pdf
    3.58
    pdf
    0.15
    pdf
    3.89
    pdf
    0.29
    pdf
    2.43
    pdf
    0.18

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    197
    1.06
    44.0
    spud mud
    485
    1.10
    44.0
    6.0
    spud mud
    1178
    1.11
    42.0
    14.0
    water based
    2550
    1.22
    49.0
    20.0
    water based
    2719
    1.27
    43.0
    13.0
    water based
    2985
    1.50
    53.0
    12.0
    water based
    3289
    1.48
    48.0
    10.0
    water based

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2945.5
    [m]
    DC
    2980.0
    [m]
    DC
    3010.0
    [m]
    DC
    3024.0
    [m]
    SWC
    3040.0
    [m]
    DC
    3056.0
    [m]
    SWC
    3061.2
    [m]
    C
    OD
    3061.3
    [m]
    C
    3061.9
    [m]
    C
    3070.0
    [m]
    DC
    3070.0
    [m]
    DC
    OD
    3075.0
    [m]
    DC
    OD
    3079.0
    [m]
    SWC
    3082.2
    [m]
    C
    OD
    3082.3
    [m]
    C
    3083.0
    [m]
    C
    3084.0
    [m]
    C
    3084.2
    [m]
    C
    OD
    3086.6
    [m]
    C
    OD
    3089.4
    [m]
    C
    3090.6
    [m]
    C
    OD
    3095.5
    [m]
    C
    OD
    3095.5
    [m]
    C
    3099.2
    [m]
    C
    OD
    3100.0
    [m]
    DC
    3110.0
    [m]
    DC
    OD
    3116.5
    [m]
    SWC
    3120.0
    [m]
    DC
    OD
    3130.0
    [m]
    DC
    OD
    3130.0
    [m]
    DC
    3140.2
    [m]
    C
    OD
    3175.0
    [m]
    DC
    3200.0
    [m]
    DC
    3230.0
    [m]
    DC
    3260.0
    [m]
    DC
    3290.0
    [m]
    DC