Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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22.11.2024 - 09:09
Time of last synchronization with Norwegian Offshore Directorate's internal systems

15/9-6

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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.
    15/9-6
    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
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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
    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.
    15/9-6
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    510-169 SP.265
    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.
    244-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.
    124
    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,
    07.05.1980
    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.
    07.09.1980
    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.
    07.09.1982
    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.
    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.
    112.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3946.0
    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).
    3945.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    3.3
    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° 27' 13.5'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 41' 31.4'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6480120.13
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    423668.06
    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.
    231

  • Wellbore history
    General
    Well 15/9-6 was drilled in the Sleipner Vest area in the Viking Graben of the North Sea. The objective of the well was to test possible hydrocarbons in Middle Jurassic sandstones on the northern flank of the 15/9-Beta structure, and to get more information about the sand distribution in this area.
    Operations and results
    Appraisal well 15/9-6 was spudded with the semi-submersible installation Nordskald on 7 May 1980 and drilled to TD at 3946 m in the Triassic Skagerrak Formation. No significant problem was encountered in the operations. The well was drilled with seawater and pre-hydrated gel down to 465 m, with sweater/gel and SSP lubricant (a vegetable oil) from 465 m to 1140 m, and with gel lignosulphonate/SSP lubricant from 140 m to TD.
    Top of the target reservoir sandstones (Callovian age Hugin Formation) was found at 3762 m. This was deeper than expected and below the field gas-water contact. The sandstones were also thinner than expected. Isolated spots of shows on sandstones were described on cuttings and cores from the Hugin and Sleipner formations and the Upper part of the Skagerrak Formation. One cuttings sample from 3346 m in the Blodøks Formation was described with good show on sandstone.
    Two cores were cut. Core 1 was cut from 3768.5 m to 3781.4 m in the Hugin Formation (75% recovery) and core 2 was cut from 3810 m to 3814.5 m in the Sleipner Formation (37% recovery). An RFT fluid sample was taken at 3774 m in the Hugin Formation. Laboratory analysis indicated the content to be a mixture of formation water, mud, and fresh water from the water cushion in the sampler.
    The well was permanently abandoned on 7 September 1980 as a dry well.
    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
    3946.00

  • 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
    3768.5
    3778.2
    [m ]
    2
    3810.0
    3811.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    11.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3768-3771m
    Core photo at depth: 3771-3773m
    Core photo at depth: 3773-3776m
    Core photo at depth: 3776-3778m
    Core photo at depth: 3810-3811m
    3768-3771m
    3771-3773m
    3773-3776m
    3776-3778m
    3810-3811m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3451.0
    [m]
    DC
    3478.0
    [m]
    DC
    3505.0
    [m]
    DC
    3532.0
    [m]
    DC
    3541.0
    [m]
    DC
    3550.0
    [m]
    DC
    3559.0
    [m]
    DC
    3586.0
    [m]
    DC
    3613.0
    [m]
    DC
    3640.0
    [m]
    DC
    3667.0
    [m]
    DC
    3685.0
    [m]
    SWC
    3694.0
    [m]
    DC
    3707.5
    [m]
    SWC
    3721.0
    [m]
    DC
    3748.0
    [m]
    DC
    3754.5
    [m]
    SWC
    3757.0
    [m]
    DC
    3763.0
    [m]
    DC
    3774.5
    [m]
    SWC
    3775.0
    [m]
    DC
    3777.5
    [m]
    C
    3784.0
    [m]
    DC
    3793.0
    [m]
    DC
    3793.5
    [m]
    SWC
    3802.0
    [m]
    DC
    3810.0
    [m]
    C
    3810.2
    [m]
    C
    3810.5
    [m]
    C
    3811.0
    [m]
    DC
    3820.0
    [m]
    DC
    3822.0
    [m]
    SWC
    3829.0
    [m]
    DC
    3838.0
    [m]
    DC
    3839.0
    [m]
    SWC
    3856.0
    [m]
    DC
    3862.0
    [m]
    SWC
    3883.0
    [m]
    DC
    3910.0
    [m]
    DC
    3928.0
    [m]
    DC
    3946.0
    [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
    19.30

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3671
    3674
    0.0
    2.0
    3637
    3638
    0.0
    3.0
    3555
    3565
    0.0
    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
    3.0
    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
    2.0
    3.0

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    1140
    3946
    FDC CNL GR
    2750
    3946
    FDC GR
    440
    2773
    HDT
    2750
    3946
    ISF SON GR
    186
    3946
    VELOCITY
    840
    3940

  • 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
    161.0
    36
    161.0
    0.00
    LOT
    SURF.COND.
    20
    425.0
    26
    440.0
    1.42
    LOT
    INTERM.
    13 3/8
    1099.0
    17 1/2
    1115.0
    2.00
    LOT
    INTERM.
    9 5/8
    2729.0
    12 1/4
    2749.0
    1.73
    LOT
    LINER
    7
    3096.0
    8 1/2
    3096.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    490
    1.04
    32.0
    waterbased
    1030
    1.17
    34.0
    waterbased
    1580
    1.21
    54.0
    waterbased
    3292
    1.35
    62.0
    waterbased
    3500
    1.45
    55.0
    waterbased

  • 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
    0.21