Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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sodir.no          Norsk
22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/9-12

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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.
    15/9-12
    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.
    SUSPENDED
    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.
    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.
    15/9-12
    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.
    309-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.
    98
    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,
    22.11.1981
    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.
    27.02.1982
    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.
    27.02.1984
    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.
    28.03.2014
    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
    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.
    NO
    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.
    MIDDLE 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.
    HUGIN FM
    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.
    110.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3740.0
    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).
    3739.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    112
    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.
    MIDDLE 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.
    SLEIPNER FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    58° 27' 23.17'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 43' 4.01'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6480390.26
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    425174.97
    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.
    330

  • Wellbore history
    General
    Well 15/9-12 was drilled as an appraisal well on the saddle area between the Alpha and Beta structures on the Sleipner Vest field in the North Sea. The main objective was to test the Middle Jurassic sandstones.
    Operations and results
    After setting anchors on 8 November 1981 the spud was delayed two weeks due to strike by the maritime and drilling crews.
    Appraisal well 15/9-12 was spudded with the semi-submersible installation Nordraug on 22 November 1981 and drilled to TD at 3740 m in the Middle Jurassic Sleipner Formation. The 36" hole was drilled to 195 m but due to bad weather the hole was lost and the well was re-spudded on 26 November. Drilling of the 26" and 17 1/2" holes went forth without significant problems other than tight spots in the lower part of the 17 1/2" hole. When setting the 9 the 5/8" casing shoe at 2755 m 64 m3 mud was lost to the formation. The well was drilled with seawater and gel slugs down to 501 m, with gel-lignosulphonate mud from 501 m to 1135 m, with lignosulphonate/gypsum/CMC mud from 1135 m to 2771 m, and with gel-lignosulphonate mud from 2771 to 3740 m.
    A 251 m thick Heimdal Formation was penetrated from 2374 m to 2625 m. The Heimdal Formation was water bearing without shows. The primary target reservoir Hugin Formation was penetrated at 3510 m and proved to contain gas-condensate with a gas-water contact at 3654 according to RFT pressure gradients. Weak shows continued on the cores down to 3665 m. The underlying Sleipner Formation was dry without shows.
    A total of 168.8 m core was cut from top to base of the Hugin Formation. The depth for cores 1 - 9 should be shifted down ca 7 m to fit with the loggers' depth. Cores 10 - 11 should be shifted 8 and 9 m down, respectively. Seven RFT runs were conducted for pressure points and sampling. Segregated fluid samples were taken at 3653 m, 3592.5 m, 3512 m, and 3647 m.
    The well was suspended on 27 February 1982 as a gas-condensate appraisal.
    Testing
    Testing was planned, but failed due to problems with the test string. For this reason Nordraug was taken to the shipyard and testing would be done in a re-entry.

  • 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]
    220.00
    3735.00

  • 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
    3504.5
    3522.2
    [m ]
    2
    3522.3
    3540.2
    [m ]
    3
    3540.2
    3553.3
    [m ]
    4
    3554.0
    3572.0
    [m ]
    5
    3572.2
    3589.8
    [m ]
    6
    3590.0
    3607.7
    [m ]
    7
    3608.0
    3625.7
    [m ]
    8
    3626.0
    3642.7
    [m ]
    9
    3644.0
    3661.6
    [m ]
    10
    3662.0
    3664.8
    [m ]
    11
    3681.0
    3692.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    168.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3504-3509m
    Core photo at depth: 3509-3514m
    Core photo at depth: 3514-3519m
    Core photo at depth: 3519-3522m
    Core photo at depth: 3522-3527m
    3504-3509m
    3509-3514m
    3514-3519m
    3519-3522m
    3522-3527m
    Core photo at depth: 3527-3532m
    Core photo at depth: 3532-3537m
    Core photo at depth: 3537-3540m
    Core photo at depth: 3540-3545m
    Core photo at depth: 3545-3550m
    3527-3532m
    3532-3537m
    3537-3540m
    3540-3545m
    3545-3550m
    Core photo at depth: 3550-3553m
    Core photo at depth: 3554-3559m
    Core photo at depth: 3559-3564m
    Core photo at depth: 3564-3569m
    Core photo at depth: 3569-3572m
    3550-3553m
    3554-3559m
    3559-3564m
    3564-3569m
    3569-3572m
    Core photo at depth: 3572-3577m
    Core photo at depth: 3577-3582m
    Core photo at depth: 3582-3587m
    Core photo at depth: 3587-3589m
    Core photo at depth: 3590-3595m
    3572-3577m
    3577-3582m
    3582-3587m
    3587-3589m
    3590-3595m
    Core photo at depth: 3595-3600m
    Core photo at depth: 3600-3605m
    Core photo at depth: 3605-3607m
    Core photo at depth: 3608-3613m
    Core photo at depth: 3613-3618m
    3595-3600m
    3600-3605m
    3605-3607m
    3608-3613m
    3613-3618m
    Core photo at depth: 3618-3623m
    Core photo at depth: 3623-3625m
    Core photo at depth: 3626-3631m
    Core photo at depth: 3631-3636m
    Core photo at depth: 3636-3641m
    3618-3623m
    3623-3625m
    3626-3631m
    3631-3636m
    3636-3641m
    Core photo at depth: 3641-3642m
    Core photo at depth: 3644-3649m
    Core photo at depth: 3649-3654m
    Core photo at depth: 3654-3659m
    Core photo at depth: 3659-3661m
    3641-3642m
    3644-3649m
    3649-3654m
    3654-3659m
    3659-3661m
    Core photo at depth: 3662-3664m
    Core photo at depth: 3681-3686m
    Core photo at depth: 3686-3691m
    Core photo at depth: 3691-3692m
    Core photo at depth:  
    3662-3664m
    3681-3686m
    3686-3691m
    3691-3692m

  • 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
    TEST1B
    3585.00
    3595.00
    14.04.1982 - 00:00
    YES
    DST
    TEST2
    3512.00
    3522.00
    20.04.1982 - 00:00
    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
    195.0
    36
    195.0
    0.00
    LOT
    SURF.COND.
    20
    501.0
    26
    515.0
    1.77
    LOT
    INTERM.
    13 3/8
    1120.0
    17 1/2
    1135.0
    1.79
    LOT
    INTERM.
    9 5/8
    2755.0
    12 1/4
    2771.0
    1.73
    LOT
    LINER
    7
    3740.0
    8 1/2
    3740.0
    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
    3585
    3595
    25.4
    2.0
    3512
    3522
    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
    2.0
    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
    253
    762000
    0.790
    0.770
    3011
    2.0
    234
    807000
    0.790
    0.760
    3448

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR
    130
    1115
    CBL VDL GR
    800
    2756
    CBL VDL GR
    2614
    3704
    CST
    2240
    2771
    CST
    2830
    3740
    DLL MSFL
    3360
    3745
    FDC CNL GR
    1120
    3746
    FDC GR
    501
    1133
    HDT
    2756
    3746
    ISF SON GR
    195
    3745
    RFT
    2380
    2705
    RFT
    3511
    3529
    RFT
    3511
    3529
    RFT
    3512
    3541
    RFT
    3541
    3638
    RFT
    3544
    3671
    RFT
    3604
    3737

  • 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
    2.33
    pdf
    22.87

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    195
    1.05
    waterbased
    815
    1.11
    waterbased
    1420
    1.12
    waterbased
    2575
    1.18
    waterbased
    3025
    1.18
    waterbased
    3190
    1.29
    waterbased
    3740
    1.50
    waterbased

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2305.0
    [m]
    SWC
    STATOIL
    2372.0
    [m]
    SWC
    STATOI
    2377.0
    [m]
    SWC
    STATOI
    2383.0
    [m]
    SWC
    STATOI
    2417.0
    [m]
    SWC
    STATOI
    2443.0
    [m]
    SWC
    STATOI
    2473.0
    [m]
    SWC
    STATOI
    2560.0
    [m]
    SWC
    STATOI
    2588.0
    [m]
    SWC
    STATOI
    2613.0
    [m]
    SWC
    STATOI
    2660.0
    [m]
    SWC
    STATOI
    2705.0
    [m]
    SWC
    STATOI
    2758.0
    [m]
    SWC
    STATOI
    3300.0
    [m]
    DC
    3330.0
    [m]
    DC
    3360.0
    [m]
    DC
    3390.0
    [m]
    DC
    3420.0
    [m]
    DC
    3450.0
    [m]
    DC
    3480.0
    [m]
    DC
    3505.0
    [m]
    DC
    3520.1
    [m]
    C
    3563.9
    [m]
    C
    3651.8
    [m]
    C
    3653.5
    [m]
    C
    3682.9
    [m]
    C
    3685.9
    [m]
    C
    3700.0
    [m]
    DC
    3720.0
    [m]
    DC
    3735.0
    [m]
    DC