Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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25.11.2024 - 01:30
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6/3-2

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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.
    6/3-2
    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.
    6/3-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    511 - 108 SP. 80
    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.
    492-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.
    110
    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,
    21.11.1985
    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.
    10.03.1986
    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.
    10.03.1988
    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
    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.
    22.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    89.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4091.0
    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).
    4085.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    154
    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 PERMIAN
    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.
    ROTLIEGEND GP
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    57° 54' 25.99'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    1° 59' 14.19'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6418975.76
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    439982.26
    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.
    862

  • Wellbore history
    General
    Well 6/3-2 was drilled on the gamma structure on an early Permian formed fault block, 1.4 km from the Norwegian/UK median line. The primary objective was to test Jurassic/Triassic sandstones at different levels for possible hydrocarbon accumulations. Secondary objectives were to test Cretaceous porous/fractured limestone/chalk and Rotliegend sandstone. The prognosed TD was 4325 m. The location was chosen due to the proximity to mature source rocks and oil/gas discoveries in British waters. Seismic anomalies indicated shallow gas. Due to this the original planned well location was abandoned and a new location was chosen 500 m to the east.
    Operations and results
    Wildcat well 6/3-2 was spudded with the semi-submersible installation ROSS Isle 21 November 1985 and drilled to TD at 4091 m in the Early Permian Rotliegend Formation. Some hole problems were experienced in the top of the 12 1/4" hole section. 9 5/8" casing was set close to the Zechstein formation before drilling the 8 1/2" hole into the salt. At 3772 m, an over-pressured zone of dolomite/slate was encountered. It was anticipated that one had found a "floating lens" enclosed in the evaporites. The well started flowing and pressure was increased to 2.05 g/cc in order to stabilise the well. Because of this a 7" liner had to be set in the middle of the salt. A 6" hole was drilled to base of the Zechstein Formation and a 5" liner was set in order to be able to reduce mud weight through the Rotliegend sandstone. The well was drilled with seawater/hi-vis pills/pre-hydrated bentonite through the top sections to 622 m, with gypsum/polymer mud from 622 m to top of the salt at 3400 m, and with Safemul oil based mud from 3400 m to TD. No indication of shallow gas was encountered at this location.
    Top Cretaceous came in at 2511 m. There were some shows in the Cretaceous limestone/chalk. However, logs, cores and cuttings showed that the reservoir properties were poor, with no fracturing, and permeabilities were less than 0.02 mD. There is a possibility that the shows are due to hydrocarbons that have migrated from the underlying Jurassic sandstone. Top Jurassic sandstone was encountered at 3017 m and extended down to 3165 m. Conglomerates are developed in a thin bed on top of the Triassic. Fair shows were recorded in the Hugin Formation, but logs showed no moveable hydrocarbons, so the shows were interpreted as residual hydrocarbons. The Rotliegend sandstone came in at 4045 m. Base was not seen. Core, cuttings and logs all proved a water-saturated formation without trace of hydrocarbons. Three cores were cut in the Cretaceous chalk between 2794 m and 2859 m, seven cores were cut in the Jurassic sandstone and into the Triassic Skagerrak Formation from 3042 m to 3197.5 m, and one core was cut at TD in the Rotliegend sandstone between 4098 m and 4091 m. FMT fluid samples were taken at 3017 m and 2652 m. Both samples contained mud filtrate and no liquid or gaseous hydrocarbons.
    The well was permanently abandoned 10 March 1986 at as dry
    Testing
    A salt-water depletion test was performed to deplete the over-pressured shale/dolomite layer in the Zechstein to be able to continue drilling to prognosed TD. The secondary objective was to determine the formation pressure in this abnormal pressure zone.
    The test interval was the open-hole section from 3722 to 3776 m with the production packer just above the 7" liner shoe at 3712. The lithology from 3722 to 3761 was mainly halite. From 3761 to 3772 m the lithology was anhydrite/halite/shale with minor amounts of dolomite. The interval from 3772 to 3776 m consisted of mainly shale interbedded with salt and porous clastic dolomite. Cumulative 21.6 Sm3 salt water was produced during the main flow period and the water flow rate decreased gradually from 234 Sm3/day to 0 Sm3/day. Initial Pressure at reference depth 3710 m, from Horner plot was 75670 KPa. Maximum-recorded temp during main flow was 145.6 deg 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]
    230.00
    4088.00

  • 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
    2794.0
    2803.5
    [m ]
    2
    2803.5
    2831.6
    [m ]
    3
    2831.6
    2859.2
    [m ]
    4
    3042.0
    3047.0
    [m ]
    5
    3049.0
    3075.1
    [m ]
    6
    3077.0
    3100.1
    [m ]
    7
    3100.0
    3127.5
    [m ]
    8
    3127.5
    3155.5
    [m ]
    9
    3155.5
    3174.1
    [m ]
    10
    3174.1
    3197.5
    [m ]
    11
    4088.0
    4089.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    218.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2794-2799m
    Core photo at depth: 2799-2803m
    Core photo at depth: 2803-2808m
    Core photo at depth: 2808-2813m
    Core photo at depth: 2813-2818m
    2794-2799m
    2799-2803m
    2803-2808m
    2808-2813m
    2813-2818m
    Core photo at depth: 2818-2823m
    Core photo at depth: 2823-2828m
    Core photo at depth: 2828-2831m
    Core photo at depth: 2831-2836m
    Core photo at depth: 2836-2841m
    2818-2823m
    2823-2828m
    2828-2831m
    2831-2836m
    2836-2841m
    Core photo at depth: 2841-2846m
    Core photo at depth: 2846-2851m
    Core photo at depth: 2851-2856m
    Core photo at depth: 2856-2859m
    Core photo at depth: 3042-3047m
    2841-2846m
    2846-2851m
    2851-2856m
    2856-2859m
    3042-3047m
    Core photo at depth: 3049-3054m
    Core photo at depth: 3043-3059m
    Core photo at depth: 3059-3064m
    Core photo at depth: 3064-3069m
    Core photo at depth: 3069-3074m
    3049-3054m
    3043-3059m
    3059-3064m
    3064-3069m
    3069-3074m
    Core photo at depth: 3074-3075m
    Core photo at depth: 3077-3082m
    Core photo at depth: 3082-3087m
    Core photo at depth: 3087-3092m
    Core photo at depth: 3092-3097m
    3074-3075m
    3077-3082m
    3082-3087m
    3087-3092m
    3092-3097m
    Core photo at depth: 3097-3100m
    Core photo at depth: 3100-3105m
    Core photo at depth: 3105-3110m
    Core photo at depth: 3110-3115m
    Core photo at depth: 3115-3120m
    3097-3100m
    3100-3105m
    3105-3110m
    3110-3115m
    3115-3120m
    Core photo at depth: 3120-3125m
    Core photo at depth: 3125-3127m
    Core photo at depth: 3127-3132m
    Core photo at depth: 3132-3137m
    Core photo at depth: 3137-3142m
    3120-3125m
    3125-3127m
    3127-3132m
    3132-3137m
    3137-3142m
    Core photo at depth: 3142-3147m
    Core photo at depth: 3147-3152m
    Core photo at depth: 3152-3155m
    Core photo at depth: 3155-3160m
    Core photo at depth: 3160-3165m
    3142-3147m
    3147-3152m
    3152-3155m
    3155-3160m
    3160-3165m
    Core photo at depth: 3165-3110m
    Core photo at depth: 3170-3174m
    Core photo at depth: 3174-3179m
    Core photo at depth: 3179-3184m
    Core photo at depth: 3184-3189m
    3165-3110m
    3170-3174m
    3174-3179m
    3179-3184m
    3184-3189m
    Core photo at depth: 3189-3194m
    Core photo at depth: 3194-3197m
    Core photo at depth: 4088-4089m
    Core photo at depth:  
    Core photo at depth:  
    3189-3194m
    3194-3197m
    4088-4089m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    3147.0
    [m]
    C
    GEOLAB
    3161.0
    [m]
    DC
    STATOIL
    3162.3
    [m]
    C
    GEOLAB
    3164.3
    [m]
    C
    GEOLAB
    3166.0
    [m]
    C
    GEOLAB
    3169.7
    [m]
    C
    GEOLAB
    3170.0
    [m]
    DC
    STATOIL
    3173.2
    [m]
    C
    GEOLAB
    3174.1
    [m]
    C
    GEOLAB
    3181.5
    [m]
    C
    GEOLAB
    3185.0
    [m]
    DC
    STATOIL
    3194.0
    [m]
    C
    GEOLAB
    3197.0
    [m]
    DC
    STATOIL
    4027.0
    [m]
    SWC
    STATOI
    4035.0
    [m]
    SWC
    STATOI

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.68

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    5.55

  • 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
    27.88

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    3776
    3772
    31.8
    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]
    ACBL VDL GR
    100
    1298
    ACBL VDL GR
    105
    600
    ACBL VDL GR
    650
    3722
    ACBL VDL GR
    3567
    4035
    CDL CNL GR CAL
    222
    4091
    DIFL BHC AC GR SP CAL
    104
    4091
    DIPLOG
    1298
    3381
    DLL MLL GR
    2461
    3324
    FMT
    2493
    2965
    FMT
    3011
    3263
    MWD
    220
    3737
    SPECTRALOG
    2950
    3377
    VELOCITY
    500
    4067

  • 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
    222.0
    36
    222.0
    0.00
    LOT
    SURF.COND.
    20
    600.0
    26
    622.0
    1.52
    LOT
    INTERM.
    13 3/8
    1300.0
    17 1/2
    1316.0
    1.53
    LOT
    INTERM.
    9 5/8
    3375.0
    12 1/4
    3387.0
    0.00
    LOT
    LINER
    7
    3722.0
    8 1/2
    3772.0
    2.14
    LOT
    LINER
    5
    4091.0
    6
    4091.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    622
    1.10
    42.0
    17.5
    WATERBASED
    25.11.1985
    760
    1.13
    46.0
    9.0
    WATER BASED
    02.12.1985
    850
    1.17
    44.0
    8.5
    WATER BASED
    02.12.1985
    1316
    1.20
    14.0
    18.0
    WATER BASED
    02.12.1985
    1316
    1.20
    60.0
    22.0
    GYP/POL
    15.12.1985
    1319
    0.00
    15.12.1985
    2028
    1.20
    18.0
    GYP/POL
    11.12.1985
    2394
    1.20
    56.0
    GYP/POL
    11.12.1985
    2394
    0.00
    15.12.1985
    2794
    1.28
    60.0
    20.0
    GYP/POL
    16.12.1985
    2794
    1.28
    62.0
    20.0
    GYP/POL
    18.12.1985
    2857
    1.28
    62.0
    19.0
    GYP/POL
    19.12.1985
    2984
    1.40
    62.0
    GYP/POL
    23.12.1985
    3028
    0.00
    06.01.1986
    3320
    1.63
    62.0
    OIL BASED
    19.01.1986
    3400
    1.50
    58.0
    OIL BASED
    13.01.1986
    3772
    1.97
    70.0
    OIL BASED
    19.01.1986
    3772
    1.97
    66.0
    OIL BASED
    19.01.1986
    3772
    1.99
    83.0
    OIL BASED
    23.01.1986
    3772
    2.00
    82.0
    OIL BASED
    23.01.1986
    3776
    2.05
    59.0
    OIL BASED
    11.02.1986
    4040
    1.80
    35.0
    OILBASED
    25.02.1986

  • Thin sections at the Norwegian Offshore Directorate
    Thin sections at the Norwegian Offshore Directorate
    Depth
    Unit
    4089.00
    [m ]
    4089.90
    [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
    0.21