Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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19.07.2024 - 01:27
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6506/6-1

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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.
    6506/6-1
    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
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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.
    6506/6-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Innline 1330 trase 1940 Strikeline 1330
    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.
    Mobil Exploration Norway INC
    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.
    977-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.
    150
    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,
    10.07.2000
    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.
    07.12.2000
    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.
    07.12.2002
    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.
    18.12.2002
    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.
    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.
    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.
    FANGST GP
    2nd level with HC, age
    Age of lithostratigraphic unit, 2nd level, where hydrocarbons were encountered. Examples of legal values: CRETACEOUS, EARLY CRETACEOUS, LATE JURASSIC, EOCENE.
    EARLY JURASSIC
    2nd level with HC, formation
    Name of lithostartigraphic unit, 2nd 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.
    BÅT GP
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    434.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    5491.0
    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).
    5474.2
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    11.84
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    200
    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.
    ÅRE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 31' 54.88'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    6° 57' 47.3'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7269443.22
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    405870.78
    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.
    4122
  • Wellbore history

    General
    PL 211 covers blocks 6506/6 and 6507/4 off-shore Norway, approximately 300 km northwest of Trondheim. Well 6506/6-1, designated as High Temperature High Pressure well, was drilled by Mobil as the first commitment well for the licence. Well 6506/6-1 was drilled in the southeastern part of Block 6506/6. The primary objective of the well was to test the hydrocarbon potential of the Bella-Donna prospect, which straddles the southern parts of blocks 6506/6 and 6507/4. A faulted, 4-way dip closed dome, with prognosed 500m of vertical closure in the Jurassic Fangst and Båt Group Sandstones was the primary objective of the well. The secondary objective was to assess the Cretaceous prospectivity.
    Operations and results
    Wildcat well 6506/6-1 was drilled with the semi-submersible installation "West Alpha". A 9 7/8" pilot hole was spudded on 7 July 2000 and drilled to 1425 m to check for the presence of shallow gas. No shallow gas was found.
    The final well was spudded on 9 July 2000 and reached TD at 5491.0 m in the Early Jurassic Åre Formation. The well was drilled with seawater and bentonite down to 1437 m, with water based KCl/Glycol mud from 1437 m to 2794 m, and with mineral oil based mud (Versapro) from 2794 m to TD. The sandstones of the Middle Jurassic Fangst Group were found to be extremely hard and abrasive and diamond impregnated bits were required to complete the section.
    The geology of the well was very much as prognosed, although the tops generally came in higher than expected. No shows were observed in the sandstones of the Cretaceous Lysing, Lange and Lyr Formations.
    The well penetrated a significant thickness of porous and permeable sandstone in the Middle Jurassic Ile and Lower Jurassic Tilje Formations. Hydrocarbons recovered from both indicate a dry gas containing 10% CO2. Petrophysical analysis indicates that lower reservoir quality Middle Jurassic Garn Formation and Lower Jurassic Upper Åre Formation sandstones are also gas charged. No water sand in the Jurassic section could be identified. Very minor oil shows were observed in the sandstones of the Middle and Lower Jurassic Fangst and Båt Groups. However, some of these could be attributed to contamination by the oil-based mud. Petrophysical and FMT sample analyses indicated that the formation fluid was dry gas, which would not have yielded either good fluorescence or cut. Gas levels, because of the overbalance, were generally very low. One core was cut in sandstones of the Garn Formation and two further cores were cut in the Tilje Formation. Three FMT hydrocarbon samples were collected from 5035.5 m in the Ile Formation and 5169 m and 5267.5 m in the Tilje Formation.
    The well was plugged and abandoned as a gas discovery on 6 December 2000.
    Testing
    Preparations were made to perform a DST in the 8 1/2" hole. However, after setting and cementing liner, gas detected during circulations indicated leak from somewhere behind the liner. It proved impossible to find the leak or seal the liner and a decision was made to abandon the test.
  • 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]
    1440.00
    5491.00
  • 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
    5001.0
    5004.4
    [m ]
    2
    5212.0
    5220.4
    [m ]
    3
    5221.5
    5275.9
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    66.1
    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
    4125.0
    [m]
    SWC
    4132.5
    [m]
    SWC
    4150.5
    [m]
    SWC
    4207.0
    [m]
    SWC
    4254.5
    [m]
    SWC
    5025.0
    [m]
    DC
    5061.0
    [m]
    DC
    5070.0
    [m]
    DC
    5106.0
    [m]
    DC
    5133.0
    [m]
    DC
    5142.0
    [m]
    DC
    5151.0
    [m]
    DC
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.69
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    1.91
    pdf
    1.99
    pdf
    1.87
    pdf
    1.50
    pdf
    0.72
  • 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
    5.14
    .pdf
    118.44
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    FMT CHT 20L-4L GR
    4966
    5346
    FMT CHT 20L-4L GR
    5267
    5268
    FMT GR 20L-4L
    5033
    5479
    HDIL XMAC ZDL CN TTRM GR
    2794
    4273
    HDIL ZDL CN ORIT TTRM GR
    4940
    5489
    HDIL ZDL CN TTRM GR
    4920
    5369
    MWD - CDR
    450
    2805
    MWD - CDR PDM
    2805
    4276
    MWD - V675 RES ADN
    5370
    5415
    MWD - V675 RES ISONIC ADN
    4276
    5370
    PMFC
    1508
    4179
    PMFC
    1509
    4152
    RCI GR
    5035
    5169
    RCOR CHT GR
    3042
    4254
    SBT CCL GR
    0
    0
    TEMP PRESS
    2524
    2524
    VSP
    2050
    5365
  • 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
    551.0
    36
    551.0
    0.00
    LOT
    SURF.COND.
    20
    1424.0
    26
    1437.0
    1.67
    LOT
    INTERM.
    13 3/8
    2784.0
    17 1/2
    2805.0
    1.88
    LOT
    INTERM.
    9 5/8
    4267.0
    12 1/4
    4276.0
    2.16
    LOT
    LINER
    7
    5491.0
    8 1/2
    5491.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    498
    1.03
    10.0
    DUMMY
    501
    1.03
    10.0
    DUMMY
    551
    1.03
    10.0
    DUMMY
    1101
    1.07
    10.0
    DUMMY
    1437
    1.07
    10.0
    DUMMY
    1437
    1.07
    10.0
    DUMMY
    2805
    0.00
    DUMMY
    2805
    0.00
    DUMMY
    2805
    1.60
    29.0
    DUMMY
    3237
    1.60
    26.0
    DUMMY
    4253
    1.64
    32.0
    DUMMY
    4276
    1.64
    33.0
    N/A
    4276
    1.64
    31.0
    DUMMY
    4390
    1.75
    36.0
    OBM
    4972
    1.89
    41.0
    OBM
    4972
    1.89
    40.0
    OBM
    4986
    1.87
    39.0
    OBM
    5005
    1.87
    40.0
    OBM
    5015
    1.87
    40.0
    OBM
    5071
    1.87
    44.0
    OBM
    5179
    1.87
    41.0
    OBM
    5222
    1.87
    40.0
    OBM
    5315
    1.87
    46.0
    OBM
    5370
    0.00
    46.0
    OBM
    5415
    1.87
    47.0
    OBM
    5491
    1.87
    45.0
    OBM
    5491
    1.87
    45.0
    OBM
  • 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
    0.28