Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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31.10.2024 - 01:27
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6306/5-1

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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.
    6306/5-1
    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
    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.
    NORWEGIAN SEA
    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.
    6306/5-1
    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.
    Amerada Hess Norge 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.
    892-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.
    33
    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,
    08.06.1997
    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.
    10.07.1997
    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.
    10.07.1999
    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.
    13.12.2005
    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
    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.
    GAS
    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.
    YES
    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.
    PALEOCENE
    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.
    EGGA FM (INFORMAL)
    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.
    227.5
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2050.0
    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).
    2044.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    9.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    74
    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.
    LATE 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.
    KVITNOS FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    63° 41' 56.42'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 33' 35.29'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7065951.07
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    379378.45
    UTM zone
    Universal Transverse Mercator zone. Examples of legal values: 31, 32, 33, 34.
    32
    NPDID wellbore
    Norwegian Offshore Directorate's unique id for the wellbore.
    3060

  • Wellbore history
    Wildcat well 6306/5-1 was drilled ca 190 km West of the town Trondheim, on the Klakk Fault Complex, which forms the border between the FrØya High and the MØre Basin. The two main objectives were to test the hydrocarbon potential of two Palaeocene prospects: the Eirikson prospect and the Nansen prospect. When drilled these prospects were prognosed as the Heimdal Formation sandstone and a new informal "Skalmen Formation sandstone", respectively. Only the Skalmen Formation was confirmed by the well. Later this formation has been encountered in other wells in the area as the (informal) Egga Formation.
    Operations and results
    Wildcat well 6306/5-1 was spudded with the semi-submersible installation Deepsea Trym on 8 June 1997. Operations went without significant problems down to the 8 1/2" section. This section was drilled from 1300 m to 1751 m, top of the Egga reservoir. This was found to be significantly over pressured and a large gain was taken. The well was shut-in and steps were taken to kill the well. The operation was complicated by the discovery that the pipe was stuck. The string was finally cut at 1477 m, and a cement plug was set to be used as kick-off plug for a sidetrack around the fish. The sidetrack was kicked off at 1365 m and drilled to TD at 2050 m in the Late Cretaceous Kvitnos Formation without further problems. The well was drilled with bentonite and seawater down to 1001 m and with ANCO 2000 mud from 1001 m to TD.
    No shallow gas or boulder beds were encountered in the uppermost well section. The well penetrated mainly clays and claystones in the Nordland, Hordaland and Rogaland groups with minor sands developed and limestone stringers present. The prognosed Heimdal Formation sands were not present. Top Egga sand was reached at 1751 m and was 12 m thick. The lithology of the Egga sand was mainly a clean sandstone divided in two by a calcareous clay stone. Top of the Egga reservoir was re-penetrated in the sidetrack at 1750 m, consisting of an upper clean sand, a shaly unit, and a thin lower sandstone bed that continued down to top Shetland Group at 1762 m. The Shetland Group consisted mainly of claystone and siltstone with minor dolomites. There were no oil shows recorded in this well. Post well organic geochemical analysis indicated mainly biogenic gas down to approximately 1650 m. Below this depth the gas was a mixture of migrated thermogenic and shallow generated biogenic/diagenetic gas. Hydrogen Index (HI) suggested fair gas and oil prone shales present in both the lower Hordaland Group and lower Tang Formation. All Formations penetrated were however immature in well position. One conventional core was cut in the Early Palaeocene Egga reservoir sand from 1757 m to 1775 m. Only 5.1 m (28.3%) was recovered. Two segregated MDT samples were taken in the Egga sand at 1755.8 m (1728.1 m TVDSS). The contents were water, mud filtrate and gas.
    The well was permanently abandoned on as a minor gas discovery.
    Testing
    No drill stem test was performed in the well.

  • 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]
    520.00
    2049.00

  • 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
    1757.0
    1762.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    5.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1757-1762m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    1757-1762m

  • 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
    324.0
    36
    324.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    480.0
    17 1/2
    507.0
    1.50
    LOT
    INTERM.
    9 5/8
    1296.0
    12 1/4
    1300.0
    2.01
    LOT
    OPEN HOLE
    2050.0
    8 1/2
    2050.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT IPL CMR GR AMS
    1200
    1392
    AIT IPL GR AMS
    1200
    2050
    AIT MFSL LSS GR AMS
    507
    1066
    AIT MFSL LSS GR AMS
    980
    1300
    CST GR
    1295
    2050
    FMI DSI GPIT GR AMS
    1200
    2050
    LDT CNL GR AMS
    507
    1300
    MDT GR
    1750
    1760
    MWD LWD - D.RAW
    252
    512
    MWD LWD - DPR TF5A
    512
    2050
    VSP
    680
    2050

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    253
    253
    1041
    1125
    1125
    1409
    1409
    1487
    1750
    1762
    1762
    1811

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.33

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.39

  • 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
    73.41

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    143
    1.62
    39.0
    ANCO 2000
    272
    0.00
    SPUD MUD
    1100
    1.66
    31.0
    ANCO 2000
    1170
    1.66
    28.0
    ANCO 2000
    1300
    1.22
    19.0
    ANCO 2000
    1505
    1.59
    30.0
    ANCO 2000
    1581
    1.20
    16.0
    ANCO 2000
    2050
    1.66
    34.0
    ANCO 2000

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    990.0
    [m]
    DC
    RRI
    1002.0
    [m]
    DC
    RRI
    1020.0
    [m]
    DC
    RRI
    1029.0
    [m]
    DC
    RRI
    1035.0
    [m]
    DC
    RRI
    1059.0
    [m]
    DC
    RRI
    1080.0
    [m]
    DC
    RRI
    1104.0
    [m]
    DC
    RRI
    1113.0
    [m]
    DC
    RRI
    1122.0
    [m]
    DC
    RRI
    1131.0
    [m]
    DC
    RRI
    1140.0
    [m]
    DC
    RRI
    1164.0
    [m]
    DC
    RRI
    1176.0
    [m]
    DC
    RRI
    1185.0
    [m]
    DC
    RRI
    1194.0
    [m]
    DC
    RRI
    1206.0
    [m]
    DC
    RRI
    1215.0
    [m]
    DC
    RRI
    1227.0
    [m]
    DC
    RRI
    1236.0
    [m]
    DC
    RRI
    1248.0
    [m]
    DC
    RRI
    1254.0
    [m]
    DC
    RRI
    1263.0
    [m]
    DC
    RRI
    1269.0
    [m]
    DC
    RRI
    1278.0
    [m]
    DC
    RRI
    1287.0
    [m]
    DC
    RRI
    1296.0
    [m]
    DC
    RRI
    1302.0
    [m]
    DC
    RRI
    1353.0
    [m]
    DC
    RRI
    1371.0
    [m]
    DC
    RRI
    1383.0
    [m]
    DC
    RRI
    1407.0
    [m]
    DC
    RRI
    1467.0
    [m]
    DC
    RRI
    1536.0
    [m]
    DC
    RRI
    1548.0
    [m]
    DC
    RRI
    1560.0
    [m]
    DC
    RRI
    1575.0
    [m]
    DC
    RRI
    1590.0
    [m]
    DC
    RRI
    1605.0
    [m]
    DC
    RRI
    1620.0
    [m]
    DC
    RRI
    1635.0
    [m]
    DC
    RRI
    1650.0
    [m]
    DC
    RRI
    1665.0
    [m]
    DC
    RRI
    1680.0
    [m]
    DC
    RRI
    1695.0
    [m]
    DC
    RRI
    1725.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI