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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30/6-21

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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.
    30/6-21
    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.
    SUSPENDED
    Multilateral
    Indicator telling if the parent well is multilateral, meaning it has more than one branch radiating from the main borehole. Example of legal values: YES, NO. See also Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    NO
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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.
    30/6-21
    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.
    537-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.
    47
    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,
    22.02.1987
    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.
    09.04.1987
    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.
    09.04.1989
    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.
    04.10.2013
    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.
    APPRAISAL
    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.
    OIL
    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.
    BRENT GP
    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).
    3100.0
    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).
    3098.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    5.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    120
    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° 38' 34.88'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 43' 47.6'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6723215.56
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    485226.44
    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.
    1037

  • Wellbore history
    General
    Well 30/6-21 was drilled on the Alpha North structure in the Oseberg fault block. Well 30/6-7 proved oil in the Ness Formation in 1982. The main purpose of well 30/6-21 was to test the hydrocarbon content in the Oseberg Formations. The well was located in a position where it could be utilized as a subsea oil producer/PTS well.
    Operations and results
    Appraisal well 30/6-21 was spudded with the semi-submersible rig Vildkat Explorer on 22 February 1987 and drilled to TD at 3100 m in Early Jurassic rocks of the Statfjord Group. Drilling proceeded without significant problems except for some tight hole problems in the upper Oseberg Formation. The well was drilled with sea water and hi-vis pills down to 664 m and with Enviromul oil based mud from 664 m to TD.
    Top Brent Group, Ness Formation was penetrated at 2575 m and proved to be oil filled down to top Dunlin at 2670.5 m. This was a down-to oil contact. The RFT data showed a fluid density of .66 g/cc. The Ness Formation proved not to be a reservoir rock due to lack of sand, while the Oseberg Formation had a net/gross ratio close to 1.0. The Cook- and Statfjord formations were both water filled.
    Four cores were cut from 2563 m at base Shetland to 2669 m at top Dunlin with close to 100% recovery. RFT fluid samples were taken at 2590 m, 2619 m, and 2660 m.
    The well was suspended on 9 April 1987 as an oil appraisal well.
    Testing
    One Drill Stem Test was performed in the interval 2645 to 2657 m in the Oseberg Formation. It produced 342 Sm3 oil and 50885 Sm3 gas /day through a 9.5 mm choke. The GOR was 149 Sm3/Sm3, the oil density was 0.847, and the gas gravity was 0.724 (air = 1). The test temperature was 106.1 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]
    660.00
    3100.00

  • 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
    2563.0
    2580.3
    [m ]
    2
    2581.0
    2596.7
    [m ]
    3
    2597.0
    2651.9
    [m ]
    4
    2652.0
    2668.7
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    104.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2568-2573m
    Core photo at depth: 2573-2578m
    Core photo at depth: 2578-2580m
    Core photo at depth: 2581-2586m
    Core photo at depth: 2586-2591m
    2568-2573m
    2573-2578m
    2578-2580m
    2581-2586m
    2586-2591m
    Core photo at depth: 2591-2596m
    Core photo at depth: 2598-2599m
    Core photo at depth: 2597-2602m
    Core photo at depth: 2602-2607m
    Core photo at depth: 2607-2612m
    2591-2596m
    2598-2599m
    2597-2602m
    2602-2607m
    2607-2612m
    Core photo at depth: 2612-2617m
    Core photo at depth: 2617-2622m
    Core photo at depth: 2622-2627m
    Core photo at depth: 2627-2632m
    Core photo at depth: 2627-2632m
    2612-2617m
    2617-2622m
    2622-2627m
    2627-2632m
    2627-2632m
    Core photo at depth: 2632-2637m
    Core photo at depth: 2637-2642m
    Core photo at depth: 2642-2647m
    Core photo at depth: 2647-2651m
    Core photo at depth: 2652-2657m
    2632-2637m
    2637-2642m
    2642-2647m
    2647-2651m
    2652-2657m
    Core photo at depth: 2657-2662m
    Core photo at depth: 2662-2667m
    Core photo at depth: 2667-2668m
    Core photo at depth:  
    Core photo at depth:  
    2657-2662m
    2662-2667m
    2667-2668m

  • 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
    DST1
    2645.50
    2657.50
    YES

  • 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
    221.0
    36
    225.0
    0.00
    LOT
    SURF.COND.
    20
    650.0
    26
    665.0
    0.00
    LOT
    INTERM.
    13 3/8
    1704.0
    17 1/2
    1720.0
    1.59
    LOT
    INTERM.
    9 5/8
    2543.0
    12 1/4
    2560.0
    1.60
    LOT
    LINER
    7
    2856.0
    8 1/2
    3100.0
    0.00
    LOT

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2646
    2658
    9.5
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    106
    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
    342
    51000
    0.847
    0.724
    149

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL CET GR
    2393
    2770
    CBL VDL GR
    1275
    1701
    CBL VDL GR
    2135
    2543
    CST
    2672
    3094
    DIL LSS GR
    2600
    3105
    DIL LSS GR CAL
    650
    2564
    DITE SDT GR
    2543
    2671
    EPT
    2545
    2930
    LDL CNL GR
    2234
    2673
    LDL CNL NGT GR CAL
    2540
    3106
    MWD - GR RES
    137
    1720
    RFT
    2578
    2660
    RFT
    2590
    0
    RFT
    2590
    2665
    RFT
    2617
    3093
    RFT
    2619
    0
    RFT
    2660
    0
    VSP
    1230
    1720

  • 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
    2.57
    pdf
    3.49

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    130
    1.50
    35.0
    11.0
    OIL BASED
    16.03.1987
    225
    1.05
    WATER
    23.02.1987
    225
    0.00
    WATER
    24.02.1987
    300
    1.00
    OIL BASED
    08.04.1987
    300
    1.00
    OIL BASED
    13.04.1987
    453
    1.06
    WATER
    25.02.1987
    615
    1.17
    WATER
    26.02.1987
    664
    1.35
    WATER
    27.02.1987
    664
    0.00
    34.0
    16.0
    OIL
    02.03.1987
    727
    1.35
    34.0
    16.0
    OIL
    02.03.1987
    1115
    1.36
    35.0
    14.0
    OIL
    02.03.1987
    1115
    0.00
    32.0
    13.0
    OIL
    03.03.1987
    1288
    1.36
    37.0
    13.0
    OIL
    04.03.1987
    1351
    1.35
    34.0
    12.0
    OIL
    05.03.1987
    1720
    1.36
    32.0
    12.0
    OIL
    06.03.1987
    1720
    0.00
    28.0
    9.0
    OIL
    09.03.1987
    1723
    1.50
    34.0
    11.0
    OIL
    10.03.1987
    2009
    1.49
    33.0
    11.0
    OIL
    11.03.1987
    2347
    1.49
    34.0
    12.0
    OIL
    12.03.1987
    2560
    1.50
    35.0
    11.0
    OIL BASED
    13.03.1987
    2560
    1.35
    23.0
    8.0
    OIL BASED
    16.03.1987
    2652
    1.36
    20.0
    7.0
    OIL BASED
    17.03.1987
    2669
    1.37
    21.0
    7.0
    OIL BASED
    18.03.1987
    2734
    1.36
    20.0
    6.0
    OIL BASED
    19.03.1987
    2799
    1.25
    19.0
    5.0
    OIL BASED
    25.03.1987
    2799
    1.25
    19.0
    5.0
    OIL BASED
    26.03.1987
    2799
    1.25
    20.0
    5.0
    OIL BASED
    30.03.1987
    2799
    1.25
    19.0
    6.0
    OIL BASED
    30.03.1987
    2799
    1.25
    23.0
    6.0
    OIL BASED
    01.04.1987
    2799
    1.25
    21.0
    6.0
    OIL BASED
    01.04.1987
    2799
    1.25
    21.0
    5.0
    OIL BASED
    02.04.1987
    2799
    1.26
    22.0
    5.0
    OIL BASED
    03.04.1987
    2799
    1.25
    22.0
    6.0
    OIL BASED
    06.04.1987
    2799
    1.25
    22.0
    8.0
    OIL BASED
    06.04.1987
    2799
    1.25
    23.0
    6.0
    OIL BASED
    07.04.1987
    2856
    1.37
    21.0
    6.0
    OIL BASED
    24.03.1987
    2860
    1.37
    20.0
    6.0
    OIL BASED
    3025
    1.37
    20.0
    7.0
    OIL BASED
    20.03.1987
    3100
    1.37
    21.0
    7.0
    OIL BASED
    5810
    1.35
    23.0
    8.0
    OIL BASED
    16.03.1987