Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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30/7-3

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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.
    30/7-3
    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.
    30/7-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    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.
    163-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.
    81
    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,
    06.08.1976
    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.
    25.10.1976
    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.
    25.10.1978
    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.
    24.09.2004
    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.
    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.
    24.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    99.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4044.0
    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).
    4043.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    119
    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 CRETACEOUS
    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.
    RØDBY FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    60° 17' 9.24'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    2° 14' 54.44'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    6683645.52
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    458441.33
    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.
    386

  • Wellbore history
    General
    Well 30/7-3 was drilled in the Fensal sub-basin south-southeast of the Hild Discovery and north of the Odin Discovery.
    The main objective of the well was to test a mapped seismic anomaly below the "Ml" marker, prognosed to be a possible porous carbonate development at Cenomanian level. The location of the well gave a test of the anomaly on the western edge, according to the seismic mapping. Secondary objectives were possible Early Cretaceous sand/limestone pinch-outs and Late Jurassic sands.
    Operations and results
    The well 30/7-3 was spudded with the semi-submersible installation Polyglomar Driller on 6 August 1976 and drilled to TD at 4044 m in the Early Cretaceous (Albian - Aptian) Cromer Knoll Group. When drilling the 12" hole at 3001 m, a leak was discovered in the wellhead. A groove was cut in the sealing area between the wellhead and the collet connector. A wellhead extension was run in the damaged wellhead with four o-rings as seal towards the original wellhead. The drilling was continued and 9 5/8"casing was set at 3782 m. While drilling 8-3/8" hole at 4044 m circulation was lost. When the mud weight was reduced in an attempt to re-establish circulation the well started to flow. A barite plug was set at bottom, and this finally stabilized the well. The well was drilled with freshwater gel to 700 m and with lignosulphonate mud from 700 m to TD.
    A comparison of the results from the seismic velocity survey and the seismic interpretations identify the interval between 3795 m and 3918 m as the target seismic anomaly. In this interval a sequence of limestone, marlstone and shale was found. The limestone is composed of mainly calcite with recognisable coccoliths. In the lower part minor terrigenous components of quartz sand and silt, and mica flakes were encountered. In places the limestone became very argillaceous grading to marlstone and shale. No visible porosity or any hydrocarbon shows were seen in this sequence.
    Minor amounts of C1 and occasional C2 were reported from about 1500 m. From about 1900 m gas concentrations of about 1% C1, with C2 and C3 coming in towards 2070 m, were seen. In Paleocene sandstone stringers (2093 m to 2407 m) a weak to good, white to yellow fluorescence with a slow to fast streaming, pale white to yellow fluorescent cut was seen, but no visible oil stain was noted on the samples. At approximately 2840 m a thin limestone gave a fair yellow fluorescence and a medium fast streaming white to yellow to fluorescent cut. The samples had no oil stain. In the limestones at approximately 3750 m fair shows were reported. No oil stain was seen, but the samples gave a pale yellow fluorescence and a slow streaming milky yellow fluorescent cut. From 4020 m a substantial increase in the background gas was seen and a peak of 15 % C1, C2 and C3 was recorded at 4029 m. Since no porous or permeable interval was described the recorded gas in this sequence was interpreted as shale gas bleeding from a highly over-pressured shale interval. The shows at 2093 m to 2407 m and at 3750 m were confirmed by post-well geochemical analyses.
    The seismic velocity survey indicated the total depth of the well to be very close to the Early Cretaceous pinch-out.
    Electrical logs were run prior to final abandonment. One conventional core was cut in the Albian ? Aptian interval from 3918.8 m to 3936.8 m (34.5 % recovery). Due to high pressure the well was permanently abandoned on 25 October 1976, before the expected TD was reached. The well is classified as dry with weak 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]
    161.00
    4040.00

  • 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
    3918.5
    3924.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    6.4
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2555.0
    [m]
    DC
    OD
    2573.0
    [m]
    DC
    OD
    2590.0
    [m]
    DC
    OD
    2608.0
    [m]
    DC
    OD
    2625.0
    [m]
    DC
    OD
    2643.0
    [m]
    DC
    OD
    2663.0
    [m]
    DC
    OD
    2683.0
    [m]
    DC
    OD
    2700.0
    [m]
    DC
    OD
    2720.0
    [m]
    DC
    OD
    2740.0
    [m]
    DC
    OD
    2760.0
    [m]
    DC
    OD
    2780.0
    [m]
    DC
    OD
    2800.0
    [m]
    DC
    OD
    2820.0
    [m]
    DC
    OD
    2840.0
    [m]
    DC
    OD
    2860.0
    [m]
    DC
    OD
    2880.0
    [m]
    DC
    OD
    2900.0
    [m]
    DC
    OD
    2920.0
    [m]
    DC
    OD
    2940.0
    [m]
    DC
    OD
    2960.0
    [m]
    DC
    OD
    2980.0
    [m]
    DC
    OD
    3000.0
    [m]
    DC
    OD
    3017.0
    [m]
    DC
    OD
    3037.0
    [m]
    DC
    OD
    3057.0
    [m]
    DC
    OD
    3077.0
    [m]
    DC
    OD
    3097.0
    [m]
    DC
    OD
    3120.0
    [m]
    DC
    OD
    3140.0
    [m]
    DC
    OD
    3160.0
    [m]
    DC
    OD
    3180.0
    [m]
    DC
    OD
    3203.0
    [m]
    DC
    OD
    3220.0
    [m]
    DC
    OD
    3240.0
    [m]
    DC
    OD
    3260.0
    [m]
    DC
    OD
    3280.0
    [m]
    DC
    OD
    3300.0
    [m]
    DC
    OD
    3320.0
    [m]
    DC
    OD
    3340.0
    [m]
    DC
    OD
    3360.0
    [m]
    DC
    OD
    3380.0
    [m]
    DC
    OD
    3400.0
    [m]
    DC
    OD
    3420.0
    [m]
    DC
    OD
    3440.0
    [m]
    DC
    OD
    3460.0
    [m]
    DC
    OD
    3480.0
    [m]
    DC
    OD
    3497.0
    [m]
    DC
    OD
    3517.0
    [m]
    DC
    OD
    3537.0
    [m]
    DC
    OD
    3557.0
    [m]
    DC
    OD
    3577.0
    [m]
    DC
    OD
    3597.0
    [m]
    DC
    OD
    3617.0
    [m]
    DC
    OD
    3637.0
    [m]
    DC
    OD
    3657.0
    [m]
    DC
    OD
    3677.0
    [m]
    DC
    OD
    3697.0
    [m]
    DC
    OD
    3717.0
    [m]
    DC
    OD
    3737.0
    [m]
    DC
    OD
    3757.0
    [m]
    DC
    OD
    3777.0
    [m]
    DC
    OD
    3797.0
    [m]
    DC
    OD
    3817.0
    [m]
    DC
    OD
    3837.0
    [m]
    DC
    OD
    3857.0
    [m]
    DC
    OD
    3877.0
    [m]
    DC
    OD
    3897.0
    [m]
    DC
    OD

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.43

  • Geochemical information

  • 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
    3.10
    pdf
    3.20
    pdf
    4.37
    pdf
    1.25
    pdf
    2.55
    pdf
    5.61
    pdf
    9.14
    pdf
    3.96
    pdf
    1.45
    pdf
    9.44
    pdf
    12.94
    pdf
    0.95
    pdf
    0.47
    pdf
    4.83
    pdf
    2.05
    pdf
    9.23
    pdf
    9.66

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    BHC GR
    120
    700
    ISF BHC GR
    684
    2654
    ISF BHC GR
    2534
    3584
    ISF BHC GR
    3525
    3786
    ISF BHC GR
    3779
    3945
    SWC
    2666
    3785
    SWC
    2700
    3765

  • 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
    159.0
    36
    173.0
    0.00
    LOT
    SURF.COND.
    20
    694.0
    26
    700.0
    0.00
    LOT
    INTERM.
    13 3/8
    2642.0
    17 1/2
    2652.0
    0.00
    LOT
    INTERM.
    9 5/8
    3782.0
    12 1/4
    3789.0
    2.31
    LOT
    OPEN HOLE
    4044.0
    8 3/8
    4044.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    161
    1.14
    125.0
    spud mud
    700
    1.08
    150.0
    11.0
    seawater
    1914
    1.12
    35.0
    15.0
    seawater
    2176
    1.14
    38.0
    21.0
    seawater
    2652
    1.20
    39.0
    15.0
    seawater
    3000
    1.50
    85.0
    35.0
    seawater
    3538
    1.75
    60.0
    19.0
    seawater
    3880
    1.82
    70.0
    22.0
    seawater
    4044
    2.11
    52.0
    17.0
    seawater