Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
24.11.2024 - 01:27
Time of last synchronization with Norwegian Offshore Directorate's internal systems

30/6-20

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    30/6-20
    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.
    30/6-20
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    NH 82 - 290 CENTER CELL 325
    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.
    506-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.
    35
    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,
    10.03.1986
    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.
    13.04.1986
    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.
    13.04.1988
    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.
    03.10.2013
    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.
    23.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    111.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3046.0
    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).
    3045.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.5
    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° 37' 20.52'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 42' 18.52'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6720920.71
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    483862.75
    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.
    892

  • Wellbore history
    General
    Well 30/6-20 was drilled on the Lambda structure west of the Oseberg Field in the North Sea. Lambda, Alpha North, Theta and Theta South are all rotated fault blocks with the Jurassic sequence dipping towards the east-northwest. The primary objective was to prove hydrocarbons in the Statfjord Group up-dip of well 30/6-16 Theta. The Statfjord Group is truncated by the base Cretaceous Unconformity to the west, and by faults to the south and east. Planned TD was ca 40 m into the Triassic Hegre Group, at a depth of ca 3025 m RKB.
    Operations and results
    Wildcat well 30/6-20 was spudded with the semi-submersible installation Treasure Scout on 10 March 1986 and drilled to TD at 3046 m in the Early Jurassic Statfjord Group. A pilot hole was drilled from 222 m to 620 m due to a shallow gas warning at 363 m. A thin sand with shallow gas was penetrated at this depth without creating any problem. Drilling proceeded without significant problems, but was delayed ca 8 days by bad weather. The well was drilled with sea water and viscous pills down to 620 m and with KCl/polymer mud from 620 m to TD.
    The Cook Formation came in at 2747 m, and Statfjord Group at 2937 m. The seismic reflector that was interpreted as top Statfjord Group proved to be top Cook Formation. This implies that the fault bounding to the east has a larger throw than first assumed. Both Cook Formation and Statfjord Group were found water bearing, but with some oil shows in the Cook Formation. RFT data indicated pressure communication between Cook and Statfjord. The first oil show in the well was described on claystone at 1990 m in the Balder Formation. Oil shows in thin limestones and claystones were seen also in the Shetland Group.
    No cores were cut and no wire line fluid samples were taken.
    The well was permanently abandoned on 13 April 1986 as a well with shows.
    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]
    630.00
    3045.00

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2267.0
    [m]
    SWC
    R.R.I
    2370.0
    [m]
    SWC
    R.R.I
    2435.0
    [m]
    SWC
    R.R.I
    2443.0
    [m]
    SWC
    R.R.I
    2645.0
    [m]
    SWC
    R.R.I
    2673.0
    [m]
    SWC
    R.R.I
    2687.0
    [m]
    SWC
    R.R.I
    2695.0
    [m]
    SWC
    R.R.I
    2715.0
    [m]
    SWC
    R.R.I
    2740.0
    [m]
    SWC
    R.R.I
    2932.0
    [m]
    SWC
    R.R.I
    2977.0
    [m]
    SWC
    R.R.I
    3037.0
    [m]
    SWC
    R.R.I

  • 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
    1.86
    pdf
    2.79

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL
    300
    770
    CST
    2267
    3037
    DIL LSS GR
    605
    1597
    DIL LSS GR
    1611
    3045
    DLWD
    221
    3044
    LDL CAL GR
    605
    1597
    LDL CNL CAL GR
    1611
    3038
    RFT
    2765
    3022
    SHDT
    2220
    3036
    VSP
    928
    3040

  • 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
    500.0
    0.00
    LOT
    SURF.COND.
    20
    603.0
    26
    623.0
    0.00
    LOT
    INTERM.
    13 3/8
    1611.0
    17 1/2
    2266.0
    2.25
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    139
    1.03
    WATER BASED
    14.04.1986
    193
    1.03
    WATER BASED
    10.03.1986
    222
    1.03
    WATER BASED
    11.03.1986
    500
    1.03
    WATER BASED
    12.03.1986
    620
    1.03
    WATER BASED
    17.03.1986
    620
    1.15
    19.0
    13.0
    WATER BASED
    21.03.1986
    620
    1.03
    WATER BASED
    13.03.1986
    620
    1.03
    WATER BASED
    16.03.1986
    620
    1.15
    WATER BASED
    18.03.1986
    623
    1.15
    18.0
    13.0
    WATER BASED
    21.03.1986
    623
    1.15
    18.0
    13.0
    WATER BASED
    24.03.1986
    623
    1.15
    22.0
    16.0
    WATER BASED
    24.03.1986
    623
    1.15
    18.0
    14.0
    WATER BASED
    24.03.1986
    1160
    1.15
    19.0
    15.0
    WATER BASED
    26.03.1986
    1396
    1.20
    20.0
    15.0
    WATER BASED
    01.04.1986
    1533
    1.39
    WATER BASED
    14.04.1986
    1606
    1.20
    20.0
    17.0
    WATER BASED
    25.03.1986
    1606
    1.23
    20.0
    23.0
    WATER BASED
    25.03.1986
    1629
    1.25
    18.0
    21.0
    WATER BASED
    25.03.1986
    1629
    1.25
    18.0
    19.0
    WATER BASED
    25.03.1986
    1790
    1.38
    22.0
    15.0
    WATER BASED
    25.03.1986
    2008
    1.38
    23.0
    15.0
    WATER BASED
    25.03.1986
    2266
    1.38
    23.0
    10.0
    WATER BASED
    02.04.1986
    2336
    1.38
    24.0
    10.0
    WATER BASED
    03.04.1986
    2493
    1.39
    31.0
    15.0
    WATER BASED
    04.04.1986
    2594
    1.38
    21.0
    11.0
    WATER BASED
    07.04.1986
    2702
    1.38
    28.0
    11.0
    WATER BASED
    07.04.1986
    2837
    1.39
    28.0
    10.0
    WATER BASED
    07.04.1986
    2958
    1.39
    30.0
    11.0
    WATER BASED
    08.04.1986
    3046
    1.39
    30.0
    11.0
    WATER BASED
    10.04.1986
    3046
    1.39
    26.0
    10.0
    WATER BASED
    11.04.1986
    3046
    1.39
    27.0
    11.0
    WATER BASED
    10.04.1986

  • 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
    0.23