Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/9-8

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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.
    15/9-8
    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.
    15/9-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    line nr610 161 SP: 349.
    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.
    279-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.
    82
    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,
    05.03.1981
    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.
    25.05.1981
    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.
    25.05.1983
    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.
    18.05.2015
    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.
    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
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    MIDDLE JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    SLEIPNER 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.
    103.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3730.0
    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).
    3729.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    128
    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° 22' 55.81'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 46' 28.32'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6472060.11
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    428335.92
    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.
    327

  • Wellbore history
    General
    Well 15/9-8 was drilled on the Delta structure in the southeastern part of the Sleipner West Field in the North Sea.  The primary objective was to delineate the hydrocarbon accumulation encountered in the 15/9-4 well on the same structure, and to get further information about the sand distribution in the area. The primary target was Callovian sandstones. Paleocene sandstone was the secondary target.
    Operations and results
    Appraisal well 15/9-8 was spudded with the semi-submersible installation Nortrym on 5 March 1981 and drilled to TD at 3730 m in the Triassic Smith Bank Formation. Operations proceeded without significant problems. The well was drilled with seawater and hi-vis pills down to 495 m, with gypsum/polymer mud from 495 m to 2845 m, and with a gel/lignosulphonate mud from m 2845 m to TD.
    The sandstones in Paleocene were water bearing. Top of the Callovian sandstone, Hugin Formation, was encountered at 3446 m, while top Sleipner Formation was encountered at 3493 m. Bothe formations proved to be gas/condensate bearing with a gas-water contact at 3564 m based on pressure gradients and well logs. No shows were recorded outside of the hydrocarbon bearing Hugin and Sleipner Formation.
    A total of 46.5 m core was recovered in four cores from the interval 3448 to 3499 m. Segregated RFT fluid samples were taken at 3460 m (gas, condensate and mud filtrate), 3561.5 m (gas, condensate and mud filtrate), and 3566.5 m (mud filtrate and a smaller quantity of gas).
    The well was permanently abandoned on 25 May 1981 as a gas/condensate appraisal well.
    Testing
    One Drill Stem Test was performed from the interval 3450 to 3460.2 m in the Hugin Formation. The test produced 255 Sm3 condensate and 820000 Sm3 gas /day through a 91/64" choke. The gas/condensate ratio was 3200 Sm3/Sm3, the condensate gravity was 0.78 g/cm3, and the gas gravity was 0.74 (air = 1). The CO2 content was 6-7%. The DST temperature was 121 °C.

  • 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
    3730.00

  • 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
    3448.4
    3465.8
    [m ]
    2
    3466.0
    3477.7
    [m ]
    3
    3477.0
    3477.5
    [m ]
    4
    3478.0
    3493.4
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    45.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3448-3451m
    Core photo at depth: 3451-3454m
    Core photo at depth: 3454-3457m
    Core photo at depth: 3457-3460m
    Core photo at depth: 3460-3463m
    3448-3451m
    3451-3454m
    3454-3457m
    3457-3460m
    3460-3463m
    Core photo at depth: 3463-3465m
    Core photo at depth: 3465-3469m
    Core photo at depth: 3469-3472m
    Core photo at depth: 3472-3475m
    Core photo at depth: 3475-3477m
    3463-3465m
    3465-3469m
    3469-3472m
    3472-3475m
    3475-3477m
    Core photo at depth: 3477-3477m
    Core photo at depth: 3478-3481m
    Core photo at depth: 3481-3484m
    Core photo at depth: 3484-3487m
    Core photo at depth: 3487-3490m
    3477-3477m
    3478-3481m
    3481-3484m
    3484-3487m
    3487-3490m
    Core photo at depth: 3490-3493m
    Core photo at depth: 3493-3494m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3490-3493m
    3493-3494m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2200.0
    [m]
    DC
    2230.0
    [m]
    DC
    2259.0
    [m]
    DC
    2289.0
    [m]
    DC
    2322.0
    [m]
    DC
    2334.0
    [m]
    DC
    2352.0
    [m]
    DC
    2382.0
    [m]
    DC
    2412.0
    [m]
    DC
    2418.0
    [m]
    DC
    2421.0
    [m]
    DC
    STATOIL
    2427.0
    [m]
    DC
    2436.0
    [m]
    DC
    STATOIL
    2442.0
    [m]
    DC
    2451.0
    [m]
    DC
    2451.0
    [m]
    DC
    STATOIL
    2460.0
    [m]
    DC
    2466.0
    [m]
    DC
    STATOIL
    2472.0
    [m]
    DC
    2481.0
    [m]
    DC
    2481.0
    [m]
    DC
    STATOIL
    2484.0
    [m]
    DC
    2493.0
    [m]
    DC
    2496.0
    [m]
    DC
    STATOIL
    2502.0
    [m]
    DC
    2511.0
    [m]
    DC
    STATOIL
    2526.0
    [m]
    DC
    2526.0
    [m]
    DC
    STATOIL
    2532.0
    [m]
    DC
    2541.0
    [m]
    DC
    STATOIL
    2542.0
    [m]
    DC
    2553.0
    [m]
    DC
    2556.0
    [m]
    DC
    STATOIL
    2571.0
    [m]
    DC
    STATOI
    2574.0
    [m]
    DC
    2580.0
    [m]
    DC
    2586.0
    [m]
    DC
    STATOIL
    2592.0
    [m]
    DC
    2601.0
    [m]
    DC
    2601.0
    [m]
    DC
    STATOIL
    2616.0
    [m]
    DC
    STATOI
    2622.0
    [m]
    DC
    2631.0
    [m]
    DC
    STATOIL
    2640.0
    [m]
    DC
    2646.0
    [m]
    DC
    2646.0
    [m]
    DC
    STATOIL
    2652.0
    [m]
    DC
    2655.0
    [m]
    DC
    STATOIL
    2658.0
    [m]
    DC
    2667.0
    [m]
    DC
    STATOIL
    2676.0
    [m]
    DC
    STATOI
    2676.0
    [m]
    DC
    2682.0
    [m]
    DC
    2688.0
    [m]
    DC
    2688.0
    [m]
    DC
    STATOIL
    2694.0
    [m]
    DC
    2697.0
    [m]
    DC
    2697.0
    [m]
    DC
    STATOIL
    2700.0
    [m]
    DC
    2703.0
    [m]
    DC
    2709.0
    [m]
    DC
    STATOIL
    2712.0
    [m]
    DC
    2718.0
    [m]
    DC
    STATOIL
    2730.0
    [m]
    DC
    STATOI
    2730.0
    [m]
    DC
    2736.0
    [m]
    DC
    2739.0
    [m]
    DC
    STATOIL
    2742.0
    [m]
    DC
    2751.0
    [m]
    DC
    STATOIL
    2760.0
    [m]
    DC
    STATOI
    2760.0
    [m]
    DC
    2772.0
    [m]
    DC
    2772.0
    [m]
    DC
    STATOIL
    2781.0
    [m]
    DC
    STATOI
    2790.0
    [m]
    DC
    2793.0
    [m]
    DC
    STATOIL
    2802.0
    [m]
    DC
    2832.0
    [m]
    DC
    2862.0
    [m]
    DC
    2886.0
    [m]
    DC
    2892.0
    [m]
    DC
    2922.0
    [m]
    DC
    2952.0
    [m]
    DC
    2982.0
    [m]
    DC
    3000.0
    [m]
    DC
    3102.0
    [m]
    DC
    3132.0
    [m]
    DC
    3162.0
    [m]
    DC
    3192.0
    [m]
    DC
    3222.0
    [m]
    DC
    3252.0
    [m]
    DC
    3282.0
    [m]
    DC
    3312.0
    [m]
    DC
    3342.0
    [m]
    DC
    3372.0
    [m]
    DC
    3402.0
    [m]
    DC
    3420.0
    [m]
    DC
    OD
    3432.0
    [m]
    DC
    3441.0
    [m]
    DC
    OD
    3448.8
    [m]
    C
    OD
    3453.9
    [m]
    C
    OD
    3460.5
    [m]
    C
    OD
    3462.0
    [m]
    C
    3472.5
    [m]
    C
    OD
    3479.3
    [m]
    C
    OD
    3482.5
    [m]
    C
    OD
    3491.7
    [m]
    C
    OD
    3492.0
    [m]
    C
    3493.0
    [m]
    C
    3493.3
    [m]
    C
    3493.3
    [m]
    C
    OD
    3499.3
    [m]
    C
    OD
    3501.0
    [m]
    DC
    OD
    3510.0
    [m]
    DC
    OD
    3519.0
    [m]
    DC
    OD
    3522.0
    [m]
    DC
    3531.0
    [m]
    DC
    OD
    3531.0
    [m]
    DC
    OD
    3540.0
    [m]
    DC
    OD
    3549.0
    [m]
    DC
    OD
    3552.0
    [m]
    DC
    3561.0
    [m]
    DC
    OD
    3570.0
    [m]
    DC
    OD
    3582.0
    [m]
    DC
    OD
    3582.0
    [m]
    DC
    3591.0
    [m]
    DC
    OD
    3600.0
    [m]
    DC
    OD
    3612.0
    [m]
    DC
    3642.0
    [m]
    DC
    3672.0
    [m]
    DC
    3702.0
    [m]
    DC
    3730.0
    [m]
    DC

  • 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
    3450.00
    3460.00
    15.05.1981 - 05:00
    YES

  • 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
    23.96
    pdf
    1.65

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3450
    3460
    36.1
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    121
    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
    255
    820000
    0.780
    0.740
    3200

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL GR
    280
    1173
    CBL GR
    1430
    2831
    CST
    3500
    3720
    DLL MSFL GR
    3390
    3730
    FDC GR
    481
    3730
    HDT
    2821
    3730
    ISF BHC GR
    178
    3730
    RFT
    3390
    3730
    VELOCITY
    800
    3725

  • 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
    179.0
    36
    179.0
    0.00
    LOT
    SURF.COND.
    20
    481.0
    26
    495.0
    1.65
    LOT
    INTERM.
    13 3/8
    1174.0
    17 1/2
    1190.0
    1.68
    LOT
    INTERM.
    9 5/8
    2831.0
    12 1/4
    2840.0
    1.82
    LOT
    LINER
    7
    3724.5
    8 1/2
    3730.0
    0.00
    LOT

  • Pressure plots
    Pressure plots
    The pore pressure data is sourced from well logs if no other source is specified. In some wells where pore pressure logs do not exist, information from Drill stem tests and kicks have been used. The data has been reported to the NPD, and further processed and quality controlled by IHS Markit.
    Pressure plots
    Document name
    Document format
    Document size [MB]
    pdf
    0.22