Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.12.2024 - 01:26
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30/6-11

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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.
    30/6-11
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/6-11
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    ST 703 146 SP 974
    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.
    Norsk Hydro Produksjon AS
    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.
    358-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.
    101
    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,
    20.12.1982
    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.
    30.03.1983
    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.
    30.03.1985
    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.
    08.12.2015
    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.
    WILDCAT
    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.
    121.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4001.0
    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).
    4001.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    6.5
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    132
    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.
    EARLY 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.
    STATFJORD GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 43' 29.38'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 44' 41.82'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6732324.06
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    486085.56
    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.
    58

  • Wellbore history
    General
    Well 30/6-11 was drilled on the Delta structure on the Flatfisk Slope, close to the northwestern end of the Oseberg Fault Block in the North Sea. The primary objective was to find hydrocarbon accumulations in the Brent Group. Secondary objective was to find additional hydrocarbon accumulations within the Early Jurassic Cook Formation and Statfjord Group. The well was placed in an area where a complete Jurassic succession could be expected. Planned TD was 75 m into the Statfjord Group.
    Operations and results
    Wildcat well 30/6-11 was spudded with the semi-submersible installation Nortrym on 20 December 1982 and drilled to TD at 4001 m in the Early Jurassic Statfjord Group. When running casing in the 17 1/2" section at 2165 m the rig had to wait on weather. Cavings accumulated as fill on the bottom and the casing was differentially stuck. Various additives were used to free the casing, including diesel. The well was drilled with seawater and hi-vis pills down to 235 m, with pre-hydrated bentonite and seawater from 235 m to 965 m, and with KCl/polymer mud from 965 m to 2165 m. From 2165 m to 3654 m, the KCl/polymer mud was slowly converted to a dispersed lignosulphonate/lignite mud and in the bottom 8 3/8" section, from 3654 m to TD a dispersed lignosulphonate/lignite mud system was used. From 2165 and downwards the diesel content in the mud was 5%, diminishing to traces below 3265 m.
    The Brent Group (3351 - 3561m) had a gross thickness of 210 m with 118 m of net sand, giving a net to gross ratio of 0.56. The average porosity of the sandstones were calculated from wireline logs to 16% with an average water saturation of 80%. The Cook Formation (3752.5 - 3768.5m) had a net sand thickness of 3 m, giving a net to gross ratio of 0,19. The average porosity of the sandstones were calculated from wireline logs to 14% with an average water saturation of 55%. The Statfjord Group (3892.5 - 4001 m) had 85 m calculated as net sand giving a net to gross ratio of 0.86. The average porosity was calculated from logs to 11% with a water saturation varying from 60-100%.
    Oil shows from both cuttings and cores together with high resistivity readings from the logs stated the presence of hydrocarbons in sandstones from the Brent Group, Cook Formation and in the very top of the Statfjord Group. All hydrocarbons were evaluated as residual. Drill stem testing and FMT sampling of the Brent Group produced no hydrocarbons. Otherwise, oil shows were described on limestone stringers in the interval 2515 m to 2635 m and on siltstones in the Late Jurassic between 3265 and 3320 m.
    Seven cores were cut in this well, one in the Late Jurassic, 5 in the Etive Formation and one in the Cook Formation sandstones. An FMT fluid sample was taken at 3463.5 m. It recovered mud filtrate and water only.
    The well was permanently abandoned on 30 March 1983 as dry with shows.
    Testing
    A drill stem test was performed from the interval 3448.5 to 3454.5 m. The test gave no flow to surface and no samples of formation fluid could be recovered from the test string.

  • 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]
    240.00
    4001.00

  • 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
    3265.0
    3266.8
    [m ]
    2
    3452.0
    3460.0
    [m ]
    3
    3461.0
    3465.9
    [m ]
    4
    3468.5
    3484.5
    [m ]
    5
    3484.5
    3501.7
    [m ]
    6
    3502.5
    3508.0
    [m ]
    7
    3756.0
    3768.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    65.3
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 3265-3266m
    Core photo at depth: 3452-3457m
    Core photo at depth: 3457-3460m
    Core photo at depth: 3461-3466m
    Core photo at depth: 3468-3473m
    3265-3266m
    3452-3457m
    3457-3460m
    3461-3466m
    3468-3473m
    Core photo at depth: 3473-3478m
    Core photo at depth: 3478-3483m
    Core photo at depth: 3483-3484m
    Core photo at depth: 3484-3489m
    Core photo at depth: 3489-3494m
    3473-3478m
    3478-3483m
    3483-3484m
    3484-3489m
    3489-3494m
    Core photo at depth: 3494-3499m
    Core photo at depth: 3499-3501m
    Core photo at depth: 3502-3507m
    Core photo at depth: 3507-3508m
    Core photo at depth: 3756-3763m
    3494-3499m
    3499-3501m
    3502-3507m
    3507-3508m
    3756-3763m
    Core photo at depth: 3763-3768m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3763-3768m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3262.5
    [m]
    SWC
    RRI
    3266.8
    [m]
    C
    RRI
    3303.5
    [m]
    SWC
    RRI
    3340.5
    [m]
    SWC
    RRI
    3349.0
    [m]
    SWC
    RRI
    3415.0
    [m]
    SWC
    RRI
    3454.5
    [m]
    C
    RRI
    3458.4
    [m]
    C
    RRI
    3461.4
    [m]
    C
    RRI
    3474.8
    [m]
    C
    RRI
    3484.5
    [m]
    C
    RRI
    3507.1
    [m]
    C
    RRI
    3540.0
    [m]
    SWC
    RRI
    3562.5
    [m]
    SWC
    RRI
    3570.0
    [m]
    DC
    FUGRO
    3586.5
    [m]
    SWC
    RRI
    3619.5
    [m]
    SWC
    RRI
    3620.0
    [m]
    DC
    FUGRO
    3635.0
    [m]
    SWC
    RRI
    3645.5
    [m]
    SWC
    RRI
    3660.0
    [m]
    SWC
    RRI
    3660.0
    [m]
    DC
    FUGRO
    3672.5
    [m]
    SWC
    RRI
    3710.0
    [m]
    DC
    FUGRO
    3711.5
    [m]
    SWC
    RRI
    3727.0
    [m]
    SWC
    RRI
    3745.0
    [m]
    DC
    FUGRO
    3756.4
    [m]
    C
    RRI
    3768.0
    [m]
    C
    RRI
    3787.0
    [m]
    DC
    FUGRO
    3798.0
    [m]
    SWC
    RRI
    3825.0
    [m]
    DC
    FUGRO
    3875.0
    [m]
    DC
    FUGRO
    3890.0
    [m]
    DC
    FUGRO
    3891.0
    [m]
    SWC
    RRI
    3896.0
    [m]
    SWC
    RRI

  • Lithostratigraphy

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.40
    pdf
    0.47
    pdf
    3.87
    pdf
    0.63

  • 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
    16.56

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3449
    3455
    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
    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

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    2850
    3634
    CCL GR
    3000
    3504
    CDL CNL CAL GR
    951
    4001
    DIFL LSBHC GR SP
    233
    4001
    DLL MLL CAL GR
    3200
    3646
    FMT
    3259
    3975
    HRD
    2103
    4001
    SWC
    1412
    4000
    VELOCITY
    913
    3985

  • 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
    235.0
    36
    235.0
    0.00
    LOT
    SURF.COND.
    20
    951.0
    26
    965.0
    1.76
    LOT
    INTERM.
    13 3/8
    2106.0
    17 1/2
    2165.0
    1.70
    LOT
    INTERM.
    9 5/8
    3639.0
    12 1/4
    3654.0
    1.93
    LOT
    OPEN HOLE
    4000.0
    8 3/8
    4001.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    220
    1.06
    waterbased
    710
    1.11
    53.0
    waterbased
    1190
    1.21
    50.0
    waterbased
    1980
    1.23
    54.0
    waterbased
    2570
    1.34
    65.0
    waterbased
    3110
    1.44
    50.0
    waterbased
    3680
    1.43
    42.0
    waterbased
    4001
    1.40
    51.0
    waterbased

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    3505.75
    [m ]
    3503.30
    [m ]
    3494.30
    [m ]
    3486.50
    [m ]
    3482.80
    [m ]
    3476.30
    [m ]
    3471.80
    [m ]
    3464.60
    [m ]
    3461.50
    [m ]
    3461.20
    [m ]
    3453.40
    [m ]
    3265.00
    [m ]

  • 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