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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6306/6-1

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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.
    6306/6-1
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6306/6-1
    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.
    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.
    791-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.
    14
    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,
    22.06.1994
    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.
    05.07.1994
    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.
    05.07.1996
    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.
    30.06.2005
    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.
    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.
    284.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    1317.0
    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).
    1317.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.3
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    43
    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.
    PRE-DEVONIAN
    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.
    BASEMENT
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    63° 30' 1.45'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 49' 14.42'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7043364.00
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    391515.49
    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.
    2384

  • Wellbore history
    General
    Well 6306/6-1 was drilled on the Frøya High in the Møre I area off shore southern Mid Norway. The main objective was to prove HC accumulations in Late Jurassic Rogn Formation sandstones, the A-prospect.
    Operations and results
    Wildcat well 6306/6-1 was spudded with the semi-submersible installation Ross Rig on 22 June 1994 and drilled to TD at 1317 m in basement rocks. No significant problems were encountered in the operations. The well was drilled with bentonite and seawater down to 432 m and with KCl/PAC mud from 432 m to TD.
    The Paleocene Egga sandstone unit was encountered at 604 m. The sandstones were rather silty; partly calcite cemented, and with reduced porosity due also to the presence of mica and glauconite. A 93 m thick Rogn Formation sandstone unit came in at 1158 m, sandwiched in Spekk Formation shales above and below. Under base Spekk a sequence of Middle Jurassic age (Fangst Group) was penetrated from 1267 m to 1281 m. Sandstones with occasional interbeds of claystone/shale grading to coals dominated this sequence. No shows were recorded in any section of the well while drilling, and since only questionable sandstone extracts were found in post-well organic geochemical analyses the well is concluded as dry. Very good source rocks are present in the well. The best source rock is seen in the upper Spekk section, which contain a typically marine anoxic, oil-prone Type II kerogen. The lower Spekk section has higher TOC, but is more terrestrial in composition and thus more gas/condensate -prone. Also the coaly shales and coals of the Middle Jurassic have very good potential for mixed oil and gas. The well is however immature all through with a vitrinite reflectance of about 0.45 % Ro at TD.
    One FMT run was performed in the Rogn Formation sandstone. Six pressure points gave a water gradient of 1.002 g/cm3. No fluid sample was taken.
    The well was permanently abandoned on 5 July as a dry hole.
    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]
    440.00
    1317.00

  • 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
    1176.0
    1194.8
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    18.8
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 1176-1181m
    Core photo at depth: 1186-1191m
    Core photo at depth: 1181-1186m
    Core photo at depth: 1191-1194m
    Core photo at depth:  
    1176-1181m
    1186-1191m
    1181-1186m
    1191-1194m

  • 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
    356.0
    36
    357.0
    0.00
    LOT
    SURF.COND.
    13 3/8
    428.0
    17 1/2
    430.0
    1.44
    LOT
    INTERM.
    9 5/8
    750.0
    12 1/4
    752.0
    1.65
    LOT
    OPEN HOLE
    1317.0
    8 1/2
    1317.0
    0.00
    LOT

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL(MAC)
    430
    750
    DIFL MAC ZDL CN SL
    750
    1317
    FMT GR
    1165
    1237
    MWD - DPR TF4
    421
    756
    MWD - DPR TF4
    756
    1176
    MWD - DPR TF4
    1176
    1317
    SWC GR
    810
    1317
    VSP
    430
    1315

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.13

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.81

  • 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
    31.77

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    610
    1.20
    15.0
    DUMMY
    756
    1.20
    12.0
    DUMMY
    759
    1.20
    12.0
    DUMMY
    1050
    1.25
    25.0
    DUMMY
    1096
    1.25
    27.0
    DUMMY
    1160
    1.25
    25.0
    DUMMY
    1191
    1.25
    27.0
    DUMMY
    1317
    1.25
    25.0
    DUMMY

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    480.0
    [m]
    DC
    MILL
    500.0
    [m]
    DC
    MILL
    520.0
    [m]
    DC
    MILL
    540.0
    [m]
    DC
    MILL
    560.0
    [m]
    DC
    MILL
    580.0
    [m]
    DC
    MILL
    600.0
    [m]
    DC
    MILL
    620.0
    [m]
    DC
    MILL
    640.0
    [m]
    DC
    MILL
    660.0
    [m]
    DC
    MILL
    680.0
    [m]
    DC
    MILL
    700.0
    [m]
    DC
    MILL
    740.0
    [m]
    DC
    MILL
    760.0
    [m]
    DC
    MILL
    770.0
    [m]
    DC
    MILL
    780.0
    [m]
    DC
    MILL
    800.0
    [m]
    DC
    MILL
    810.0
    [m]
    DC
    MILL
    820.0
    [m]
    DC
    MILL
    830.0
    [m]
    DC
    MILL
    840.0
    [m]
    DC
    MILL
    850.0
    [m]
    DC
    MILL
    860.0
    [m]
    DC
    MILL
    870.0
    [m]
    DC
    MILL
    879.5
    [m]
    SWC
    STATO
    887.5
    [m]
    SWC
    STATO
    900.0
    [m]
    DC
    MILL
    910.0
    [m]
    DC
    MILL
    920.0
    [m]
    DC
    MILL
    925.5
    [m]
    SWC
    STATO
    940.0
    [m]
    DC
    MILL
    950.0
    [m]
    DC
    MILL
    960.0
    [m]
    DC
    MILL
    969.0
    [m]
    DC
    MILL
    978.0
    [m]
    DC
    MILL
    987.0
    [m]
    DC
    MILL
    993.0
    [m]
    SWC
    STATO
    1005.0
    [m]
    DC
    MILL
    1014.0
    [m]
    DC
    MILL
    1023.0
    [m]
    DC
    MILL
    1032.0
    [m]
    DC
    MILL
    1041.0
    [m]
    DC
    MILL
    1046.5
    [m]
    SWC
    STATO
    1059.0
    [m]
    DC
    MILL
    1068.0
    [m]
    DC
    MILL
    1077.0
    [m]
    DC
    MILL
    1086.0
    [m]
    DC
    MILL
    1095.0
    [m]
    DC
    MILL
    1104.0
    [m]
    DC
    MILL
    1113.0
    [m]
    DC
    MILL
    1122.0
    [m]
    DC
    MILL
    1131.0
    [m]
    DC
    MILL
    1137.5
    [m]
    SWC
    STATO
    1143.0
    [m]
    DC
    MILL
    1152.0
    [m]
    DC
    MILL
    1160.5
    [m]
    SWC
    STATO
    1170.0
    [m]
    DC
    MILL
    1176.1
    [m]
    C
    APT
    1177.0
    [m]
    C
    STATOIL
    1178.6
    [m]
    C
    APT
    1180.4
    [m]
    C
    APT
    1182.0
    [m]
    C
    APT
    1182.0
    [m]
    C
    STATOIL
    1184.0
    [m]
    C
    APT
    1186.2
    [m]
    C
    APT
    1187.6
    [m]
    C
    APT
    1189.0
    [m]
    C
    APT
    1191.0
    [m]
    C
    APT
    1193.3
    [m]
    C
    APT
    1201.0
    [m]
    SWC
    STATOIL
    1212.0
    [m]
    DC
    MILL
    1228.8
    [m]
    SWC
    STATOIL
    1236.0
    [m]
    DC
    MILL
    1248.0
    [m]
    DC
    MILL
    1259.5
    [m]
    SWC
    STATOIL
    1261.5
    [m]
    SWC
    STATOI
    1267.0
    [m]
    DC
    MILL
    1273.0
    [m]
    DC
    MILL
    1276.0
    [m]
    DC
    MILL
    1279.0
    [m]
    DC
    MILL
    1282.0
    [m]
    DC
    MILL
    1285.0
    [m]
    DC
    MILL
    1297.0
    [m]
    DC
    MILL