Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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6507/7-8

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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.
    6507/7-8
    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.
    6507/7-8
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    CN 8502 - 482 SP. 570
    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.
    550-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.
    55
    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,
    09.06.1987
    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.
    02.08.1987
    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.
    02.08.1989
    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
    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
    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.
    MIDDLE 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.
    ILE 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.
    332.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2855.0
    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).
    2855.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    1.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    96
    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° 17' 52.68'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 18' 49.87'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7242895.96
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    421377.09
    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.
    1071

  • Wellbore history
    General
    Well 6507/7-8 is a replacement well for well 6507/7-7 and was drilled on the southern flank of the Heidrun Field on the Halten Terrace. The primary objective was to appraise reserves in this part of the field. Further objectives were to obtain a water sample from the Aldra (Tilje) Formation, evaluate vertical communication between sandstone units in the Tomma Formation (Fangst Group), and to obtain oriented cores from this section for fracture orientation studies.
    Operations and results
    Appraisal well 6507/7-8 was spudded with the semi-submersible installation Treasure Hunter on 9 June 1987 and drilled to TD at 2855 m in Early Jurassic sediments of the Åre Formation. Some problems with low penetration rate and bit balling occurred in the 17 1/2" section in swelling clay, sometimes interbedded with pebbles. The well was drilled with seawater and gel sweeps down to 1035 m and with KCl/polymer mud from 1035 m to TD.
    The top of the Tertiary was encountered at 604 m. No indications of overpressured shallow gas were seen. The top of the Tomma Formation (Fangst Group) was penetrated at 2436.2 m and consisted of two hydrocarbon bearing sandstone units separated by a ca 2 m thick shaley interval at 2468 m. For the two units as a whole the logs gave an average SW of 19.4% over the 60.6 m reservoir and a net/gross ratio of 0.921. RFT pressure data indicated a common pressure regime across the shale band at 2468 m, with an OWC at 2495 m. Oil shows were first observed on cores at 2435.5 m where a uniform light buff coloured oil stain was observed. It had pale yellow fluorescence and gave a pale yellow fast blooming cut. Below this the cut was predominantly fast and streaming. A dark brown residue was observed after the solvent had evaporated. With depth the residue became medium brown. Below 2464 m the shows became patchy with the cut residue becoming a pale yellowish grey. No shows were observed below the OWC.
    Seven cores were cut from 2405 m in the Melke Formation, through the Fangst Group, and down to 2525 m in the Ror Formation. The average core recovery was 98%. 30 RFT pressure tests were taken through the reservoir. No fluid samples were taken on wire line.
    The well was permanently abandoned on 2 August 1987 as an oil and gas appraisal.
    Testing
    Two DST's were conducted in the intervals 2473 m to 2480 m (DST 1) and 2438 m to 2441 m (DST 2). DST 1 flowed 30 deg API oil at 187 Sm3/day and gas at 19900 Sm3/day through a 20/64" choke. The gas gravity was 0.68 (air = 1) and the GOR was 106 Sm3/Sm3. DST 2 flowed 29 API oil at 1105 Sm3/day and gas at 136570 Sm3/day through a 52/64" choke. The gas gravity was 0.7 (air = 1) and the GOR was 124 Sm3/Sm3. The gauge temperatures recorded in the tests were 90.3 and 86.7 deg C in DST 1 and DST 2, respectively.
    The results of the well test did not indicate vertical communication across the shaley interval at 2468 m.

  • 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]
    1035.00
    2855.00

  • 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
    2405.0
    2423.5
    [m ]
    2
    2423.5
    2441.7
    [m ]
    3
    2442.0
    2458.9
    [m ]
    4
    2460.1
    2479.0
    [m ]
    5
    2479.0
    2497.3
    [m ]
    6
    2497.5
    2516.8
    [m ]
    7
    2516.0
    2525.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    119.1
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • 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
    2473.00
    2480.00
    19.07.1987 - 00:00
    YES
    DST
    DST2
    2438.00
    2441.00
    21.07.1987 - 00:00
    YES

  • Lithostratigraphy
    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    357
    357
    1463
    1877
    1877
    1997
    1997
    2023
    2082
    2384
    2384
    2436
    2436
    2468
    2470
    2497
    2497
    2558
    2787

  • 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
    12.90
    pdf
    2.95
    pdf
    12.42

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2473
    2480
    7.9
    2.0
    2441
    2438
    20.6
    2.1
    2441
    2438
    20.6
    2.2
    2441
    2438
    20.6
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    8.000
    2.0
    8.000
    2.1
    8.000
    2.2
    8.000
    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
    175
    0.882
    0.670
    80
    2.0
    1145
    99000
    0.882
    0.670
    86
    2.1
    1145
    0.887
    0.700
    86
    2.2
    1137
    0.887
    0.700
    87

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL CCL
    2015
    2530
    DIL MSFL SDT GR SP
    2399
    2828
    DLL LDL CNL NGL CAL GR
    2399
    2828
    FMS GR
    2399
    2835
    MWD - GR RES DIR
    473
    2855
    RFT GR
    2439
    2797
    SDT CBL
    800
    2398
    VSP
    1200
    2825
    VSP
    2360
    2600

  • 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
    468.0
    36
    1035.0
    1.02
    LOT
    SURF.COND.
    20
    1027.2
    26
    1054.0
    1.51
    LOT
    INTERM.
    13 3/8
    2398.5
    17 1/2
    2403.0
    1.84
    LOT
    INTERM.
    9 5/8
    2833.5
    12 1/4
    2855.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    466
    1.04
    WATER BASED
    11.06.1987
    470
    1.04
    WATER BASED
    15.06.1987
    544
    1.04
    WATER BASED
    15.06.1987
    1021
    1.03
    WATER BASED
    15.06.1987
    1035
    1.04
    WATER BASED
    16.06.1987
    1035
    1.04
    WATER BASED
    17.06.1987
    1035
    1.04
    WATER BASED
    18.06.1987
    1035
    1.04
    WATER BASED
    19.06.1987
    1035
    1.04
    WATER BASED
    22.06.1987
    1054
    1.16
    WATER BASED
    22.06.1987
    1211
    1.17
    WATER BASED
    22.06.1987
    1541
    1.28
    WATER BASED
    23.06.1987
    1795
    1.32
    WATER BASED
    24.06.1987
    1953
    1.38
    WATER BASED
    25.06.1987
    2198
    1.40
    WATER BASED
    26.06.1987
    2199
    1.40
    WATER BASED
    29.06.1987
    2344
    1.42
    WATER BASED
    29.06.1987
    2359
    1.42
    WATER BASED
    29.06.1987
    2403
    1.42
    WATER BASED
    30.06.1987
    2403
    1.20
    WATER BASED
    02.07.1987
    2403
    1.42
    18.0
    5.8
    WATER BASED
    01.07.1987
    2405
    1.21
    11.0
    19.0
    WATER BASED
    03.07.1987
    2429
    1.21
    17.0
    8.2
    WATER BASED
    06.07.1987
    2465
    1.21
    16.0
    7.2
    WATER BASED
    06.07.1987
    2513
    1.21
    15.0
    7.2
    WATER BASED
    06.07.1987
    2525
    1.21
    14.0
    6.7
    WATER BASED
    07.07.1987
    2614
    1.20
    15.0
    10.1
    WATER BASED
    13.07.1987
    2658
    1.20
    15.0
    7.2
    WATER BASED
    13.07.1987
    2855
    1.20
    13.0
    2.4
    WATER BASED
    14.07.1987
    2855
    1.19
    9.0
    5.8
    WATER BASED
    20.07.1987
    2855
    1.20
    16.0
    7.7
    WATER BASED
    13.07.1987
    2855
    1.21
    19.0
    5.3
    WATER BASED
    13.07.1987
    2855
    1.19
    12.0
    2.4
    WATER BASED
    15.07.1987
    2855
    1.19
    12.0
    2.4
    WATER BASED
    16.07.1987
    2855
    1.19
    10.0
    6.2
    WATER BASED
    17.07.1987
    2855
    1.19
    8.0
    5.3
    WATER BASED
    20.07.1987
    2855
    1.19
    8.0
    5.3
    WATER BASED
    21.07.1987
    2855
    1.19
    8.0
    5.3
    WATER BASED
    22.07.1987
    2855
    1.19
    8.0
    5.3
    WATER BASED
    23.07.1987
    2855
    1.19
    8.0
    5.3
    WATER BASED
    24.07.1987
    2855
    1.19
    9.0
    5.7
    WATER BASED
    27.07.1987
    2855
    1.19
    9.0
    4.8
    WATER BASED
    28.07.1987
    2855
    0.00
    WATER BASED
    29.07.1987
    2855
    0.00
    WATER BASED
    31.07.1987
    2855
    0.00
    WATER BASED
    03.08.1987

  • 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