Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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11.11.2024 - 01:26
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6507/7-3

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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.
    6507/7-3
    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).
    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.
    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.
    NORWEGIAN 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.
    6507/7-3
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    BP 83 - 307 SP. 820
    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.
    Conoco 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.
    475-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.
    52
    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,
    29.07.1985
    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.
    18.09.1985
    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.
    18.09.1987
    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.
    18.12.2008
    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
    Reclassified from wellbore
    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.
    OIL/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.
    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.
    GARN FM
    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.
    346.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2850.0
    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).
    2850.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.75
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    98
    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° 19' 1.31'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 17' 44.79'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7245042.82
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    420591.73
    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.
    482

  • Wellbore history
    General
    Appraisal well 6507/7-3 was drilled in the northern part of the Haltenbanken area, some 190 km west of the Norwegian coast. It was drilled to evaluate the "B" prospect in the intensely faulted zone that lies at the intersection of the Nordland Ridge in the northeast and the Halten Terrace in the south. The prospect was in a southward plunging horst block formed by a Late Jurassic tensional fault system. The well was drilled down dip from the 6507/7-2 discovery well. It was designed to test the Middle Jurassic sands to determine whether an oil leg was present.
    Operations and results
    Well 6507/7-3 was spudded with the semi-submersible installation Nortrym on 29 July 1985 and drilled to TD at 2850 m in Early Jurassic sediments of the Åre Formation. Few problems were experienced during operations on 6507/7-3, those that did occur were predominantly related to gumbo and tight hole conditions. There were no serious accidents or problems during the operation. A total of 54 days was spent on drilling, logging, testing, and completion. The well was drilled with sea water and gel sweeps down to 1030 m, and with gypsum/polymer mud from 1030 m to TD.
    The Late Cretaceous (Santonian) was found directly overlying the Middle Jurassic (Callovian) Fangst Group as anticipated. No hydrocarbon fluorescence or staining was observed until the top of the Fangst Group at 2367.5 m. The Fangst and Båt Group was found oil bearing down to claystones belonging to the Ror Formation at 2540 m. Patchy fluorescence and a slight hydrocarbon odour persisted down to 2448 m. Using gradients established from electric logs, excellent RFT pressure data, and fluid analysis, the true oil/water contact was however indicated to be at 2491 m. No hydrocarbon fluorescence or staining was observed on cores or ditch cuttings below 2448 m.
    Thirteen cores were cut from 2360 to 2470 m and 2500 to 2662 m with 96% recovery from the Late Cretaceous through to the Early Jurassic. Analysis of cores and logs indicated good porosities and permeabilities, particularly in the upper section. RFT fluid sampling was done in the Fangst and Båt Groups at 2390 m, 2393 m, 2395 m, 2410 m, 2417 m, 2432 m, 2433.5 m, and 2444.5 m
    The well was abandoned on 18 September 1985 as an oil and gas appraisal well.
    Testing
    Three drill stem tests were undertaken, all of them testing the oil-bearing sands of the Fangst Group. The intervals perforated were: 2413 - 2430 m (DST 1), 2385 - 2400 m (DST 2), and 2368 - 2380 m (DST 3). At stabilized conditions on various choke sizes, peak production of oil on test was 870 Sm3/ day (5465 BOPD), with an oil gravity of 29 deg API. Associated gas production was 93000 Sm3/day (3.285 MMCFD) with a gravity of 0.67 with respect to air. The average temperatures measured at gauge carrier depth were 86.1, 85.9, and 84.8 deg C in DST, DST 2, and DST 3, respectively

  • 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]
    460.00
    2846.00

  • 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
    2360.0
    2360.7
    [m ]
    2
    2361.0
    2376.6
    [m ]
    3
    2381.0
    2386.7
    [m ]
    4
    2386.1
    2414.5
    [m ]
    5
    2415.0
    2442.8
    [m ]
    6
    2442.8
    2471.0
    [m ]
    7
    2500.0
    2519.7
    [m ]
    8
    2521.0
    2541.7
    [m ]
    9
    2543.0
    2569.1
    [m ]
    10
    2570.0
    2586.5
    [m ]
    11
    2587.0
    2616.5
    [m ]
    12
    2615.5
    2643.0
    [m ]
    13
    2643.0
    2661.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    264.4
    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
    2141.0
    [m]
    DC
    OD
    2159.0
    [m]
    DC
    OD
    2186.0
    [m]
    DC
    OD
    2201.0
    [m]
    DC
    OD
    2231.0
    [m]
    DC
    OD
    2255.0
    [m]
    C
    OD
    2270.0
    [m]
    DC
    OD
    2321.0
    [m]
    DC
    OD
    2345.0
    [m]
    DC
    OD
    2359.1
    [m]
    C
    SAGA
    2359.5
    [m]
    C
    SAGA
    2360.0
    [m]
    C
    OD
    2360.3
    [m]
    C
    OD
    2361.0
    [m]
    C
    OD
    2361.7
    [m]
    C
    OD
    2362.6
    [m]
    C
    OD
    2362.9
    [m]
    C
    OD
    2363.4
    [m]
    C
    OD
    2363.7
    [m]
    C
    OD
    2364.0
    [m]
    C
    OD
    2365.0
    [m]
    C
    OD
    2365.5
    [m]
    C
    SAGA
    2365.5
    [m]
    C
    OD
    2366.0
    [m]
    C
    OD
    2366.3
    [m]
    C
    OD
    2367.0
    [m]
    C
    OD
    2367.3
    [m]
    C
    OD
    2367.4
    [m]
    C
    SAGA
    2367.6
    [m]
    C
    SAGA
    2367.7
    [m]
    C
    OD
    2368.0
    [m]
    C
    OD
    2373.0
    [m]
    C
    OD
    2376.0
    [m]
    C
    OD
    2382.7
    [m]
    C
    OD
    2383.5
    [m]
    C
    OD
    2404.0
    [m]
    C
    OD
    2408.4
    [m]
    C
    OD
    2410.9
    [m]
    C
    OD
    2469.5
    [m]
    C
    OD
    2471.1
    [m]
    C
    OD
    2523.1
    [m]
    C
    OD

  • 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
    2413.00
    2430.00
    03.09.1985 - 00:00
    YES
    DST
    DST2
    2385.00
    2400.00
    08.09.1985 - 00:00
    YES
    DST
    DST3
    2368.00
    2380.00
    12.09.1985 - 00:00
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    371
    371
    1472
    1906
    1906
    1990
    1990
    2021
    2081
    2368
    2368
    2400
    2412
    2434
    2434
    2499
    2720

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.79
    pdf
    2.65

  • 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
    12.38
    pdf
    1.92

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2413
    2430
    21.0
    2.0
    2385
    2400
    24.0
    3.0
    2368
    2380
    25.4
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    6.000
    5.000
    25.000
    88
    2.0
    6.000
    4.000
    25.000
    87
    3.0
    6.000
    5.000
    25.000
    85
    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
    772
    86027
    0.870
    0.680
    112
    2.0
    870
    93021
    0.909
    0.737
    227
    3.0
    823
    89510
    0.808
    0.745
    417

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL VDL GR CCL
    1500
    2804
    CBL VDL GR CCL
    2291
    2291
    CST
    2310
    2832
    DIL LSS GR SP
    2292
    2847
    DLL MSFL GR SP
    2292
    2706
    FDC CNL GR
    2140
    2846
    ISF LSS MSFL GR SP
    469
    1027
    ISF LSS MSFL GR SP
    1024
    2137
    LDT CNL GR
    1024
    2140
    LDT CNL NGS
    2292
    2845
    MWD - GYRO MULTISHOT
    375
    2834
    RFT
    2369
    2601
    SHDT
    2235
    2845
    VSP
    473
    2834

  • 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
    469.0
    36
    469.0
    0.00
    LOT
    SURF.COND.
    20
    1024.0
    26
    1030.0
    1.49
    LOT
    INTERM.
    13 3/8
    2291.0
    17 1/2
    2307.0
    1.75
    LOT
    INTERM.
    13 3/8
    2307.0
    17 1/2
    2360.0
    1.75
    LOT
    INTERM.
    9 5/8
    2832.0
    12 1/4
    2850.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    469
    1.14
    100.0
    57.5
    WATER BASED
    30.07.1985
    469
    1.03
    100.0
    47.8
    WATER BASED
    31.07.1985
    469
    1.07
    100.0
    WATER BASED
    30.07.1985
    469
    1.14
    100.0
    57.5
    WATER BASED
    30.07.1985
    469
    1.03
    100.0
    47.8
    WATER BASED
    31.07.1985
    1030
    1.16
    8.0
    37.6
    WATER BASED
    05.08.1985
    1030
    1.14
    7.0
    234.6
    WATER BASED
    01.08.1985
    1030
    1.16
    8.0
    37.6
    WATER BASED
    05.08.1985
    1035
    1.09
    48.0
    105.0
    WATER BASED
    07.08.1985
    1630
    1.29
    59.0
    105.0
    WATER BASED
    08.08.1985
    1983
    1.38
    22.0
    148.4
    WATER BASED
    09.08.1985
    2248
    1.38
    27.0
    1056.0
    WATER BASED
    08.08.1985
    2307
    1.38
    26.0
    105.6
    WATER BASED
    08.08.1985
    2307
    1.38
    25.0
    96.0
    WATER BASED
    12.08.1985
    2307
    1.26
    15.0
    67.2
    WATER BASED
    12.08.1985
    2307
    1.26
    16.0
    62.4
    WATER BASED
    13.08.1985
    2307
    1.39
    23.0
    1008.0
    WATER BASED
    08.08.1985
    2307
    1.38
    26.0
    105.6
    WATER BASED
    08.08.1985
    2307
    1.38
    25.0
    96.0
    WATER BASED
    12.08.1985
    2307
    1.26
    15.0
    67.2
    WATER BASED
    12.08.1985
    2307
    1.26
    16.0
    62.4
    WATER BASED
    13.08.1985
    2360
    1.26
    17.0
    67.2
    WATER BASED
    15.08.1985
    2381
    1.26
    18.0
    99.0
    WATER BASED
    19.08.1985
    2419
    1.26
    19.0
    96.0
    WATER BASED
    19.08.1985
    2470
    1.26
    19.0
    96.0
    WATER BASED
    19.08.1985
    2521
    1.26
    18.0
    115.0
    WATER BASED
    17.08.1985
    2566
    1.26
    18.0
    23.0
    WATER BASED
    21.08.1985
    2588
    1.26
    19.0
    110.4
    WATER BASED
    21.08.1985
    2643
    1.27
    21.0
    124.8
    WATER BASED
    23.08.1985
    2776
    1.27
    19.0
    115.2
    WATER BASED
    26.08.1985
    2850
    1.27
    16.0
    105.0
    WATER BASED
    26.08.1985
    2850
    1.27
    16.0
    95.7
    WATER BASED
    24.08.1985

  • 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
    0.27