Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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14.07.2024 - 01:28
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6507/12-1

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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.
    6507/12-1
    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
    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
    Well name
    Official name of the parent well for the wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6507/12-1
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    803-472 SP.590
    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.
    Saga Petroleum ASA
    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.
    255-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.
    118
    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,
    01.07.1980
    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.
    26.10.1980
    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.
    26.10.1982
    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.
    29.06.2004
    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.
    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.
    25.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    225.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3720.0
    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).
    3712.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    19.6
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    131
    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.
    TRIASSIC
    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.
    RED BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 7' 1.62'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 42' 42.61'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7222304.75
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    439520.78
    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.
    202
  • Wellbore history

    General
    Wildcat well 6507/12-1 was the first well to be drilled offshore Mid-Norway. It was drilled to test the stratigraphic sequence between seabed and at least 500 m below "reflector E" as defined in the licence agreement. The primary target was a mapped Intra Jurassic seismic reflector at a depth of approximately 2575 m. This reflector was interpreted to be associated with a Middle to Early Jurassic sandstone sequence. The secondary target was represented by possible sandstone sequences between the mapped Base Cretaceous reflector and the Intra Jurassic reflector. Thirdly there was a small vertical closure in the basal part of the Tertiary sequence that could have prospective interest.
    The well is Type Well for the Båt Group, the Tare Formation and the Naust Formation. It is Reference Well for the Fangst Group.
    Operations and results
    The well was spudded with the semi-submersible installation Byford Dolphin on 1 July 1980 in a water depth of 225 m, and drilled to a total depth of 3713 m in Late Triassic Red Beds. The well was drilled with spud mud down to 778 m, with Gypsum PAC mud from 778 m to 1448 m, and with Lignosulfonate/PAC mud from 1448 m to TD.
    The well penetrated a section of 1105 m below reflector E and thus meets the requirement set in the work programme for licence 059.
    The well encountered a Cenozoic sequence of 1679 m and the Tertiary succession was, at the time the well was drilled, subdivided into lithostratigraphic units according to Deegan & Scull's nomenclature for the northern North Sea. The well proved a slightly thicker Tertiary sequence than expected. The seismic leg interpreted to represent Base Tertiary proved to be related to a tuff sequence (Tare Formation).
    The Top Cretaceous reflector was easily determined from acoustic and density logs. The base of the Cretaceous was encountered in the well at 2032 m. The prognosed depth was 1975 m. The Cretaceous sequence is composed of Late Cretaceous variegated claystones and Early Cretaceous red marls overlying a basal limestone. Total Cretaceous thickness is 103 m. The sequence of primary interest below the Base Cretaceous unconformity starts with a 20 m thick black shale equivalent to the Kimmeridge Clay Formation (Spekk Formation). At 2052 m a very fine-grained marginal marine silty sandstone/clay-stone of Bathonian-Callovian/Oxfordian age was encountered (Melke Formation). Below this section the well penetrated several sandstone sections with good to excellent reservoir quality (Fangst and Båt Groups). The reflector that defined the top of the primary target was penetrated at 2660 m. It fell within a succession of coals and coaly claystones interstratified with sandstones of delta plain character (+re Formation). The base of the Coal Unit is of Late Rhaetian age while the top is defined well into the Early Jurassic. No hiatuses were recorded at the Triassic-Jurassic boundary. Below the coal sequence the well found a thick late Triassic continental succession, of which the lower 653 m is of red bed facies similar to the Cormorant Unit as seen in the northern North Sea. The well was extended to a TD of 3713 m, 213 m deeper than the planned maximum total depth of 3500 m in order to obtain more stratigraphic information. With the exception of slight traces of apparently dead oil reported at 2550 - 2560 m (by EXLOG), and a weak cut reaction seen on a sidewall core 2743.5 m and 2766 m, no oil shows were reported during the drilling of this well. There were no indications of hydrocarbons seen from the E-logs. Four conventional cores were cut in the "Coal Unit". The first was cut from 2404 m to 2410 m in the Tilje Formation, cores two and three were cut in the "Coal Unit" (+re Formation) in the intervals 2520.5 m to 2538 m and 2707 m to 2716 m, respectively, and core number 4 was cut from 3708 m to 3720 m in the Red Beds. One attempt was made to sample formation water. Due to sampling problems, the retrieved sample was a mixture of fluid from 2451.5 m and 2840 m. The well was permanently abandoned on 26 October 1980 as a dry well.
    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]
    380.00
    3717.00
  • 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
    2404.0
    2405.7
    [m ]
    2
    2520.0
    2537.3
    [m ]
    3
    2707.0
    2715.8
    [m ]
    4
    3708.0
    3719.0
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    38.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2404-2405m
    Core photo at depth: 2520-2522m
    Core photo at depth: 2523-2525m
    Core photo at depth: 2526-2528m
    Core photo at depth: 2529-2530m
    2404-2405m
    2520-2522m
    2523-2525m
    2526-2528m
    2529-2530m
    Core photo at depth: 2531-2533m
    Core photo at depth: 2534-2536m
    Core photo at depth: 2537-2538m
    Core photo at depth: 2707-2709m
    Core photo at depth: 2710-2712m
    2531-2533m
    2534-2536m
    2537-2538m
    2707-2709m
    2710-2712m
    Core photo at depth: 2713-2715m
    Core photo at depth: 2715-2716m
    Core photo at depth: 3708-3710m
    Core photo at depth: 3710-3713m
    Core photo at depth: 3714-3716m
    2713-2715m
    2715-2716m
    3708-3710m
    3710-3713m
    3714-3716m
    Core photo at depth: 3716-3718m
    Core photo at depth: 3719-3719m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    3716-3718m
    3719-3719m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1560.0
    [m]
    DC
    IKU
    1590.0
    [m]
    DC
    IKU
    1600.0
    [m]
    DC
    IKU
    1620.0
    [m]
    DC
    IKU
    1640.0
    [m]
    DC
    IKU
    1660.0
    [m]
    DC
    IKU
    1680.0
    [m]
    DC
    IKU
    1700.0
    [m]
    DC
    IKU
    1720.0
    [m]
    DC
    IKU
    1740.0
    [m]
    DC
    IKU
    1760.0
    [m]
    DC
    IKU
    1780.0
    [m]
    DC
    IKU
    1800.0
    [m]
    DC
    IKU
    1820.0
    [m]
    DC
    IKU
    1840.0
    [m]
    DC
    IKU
    1860.0
    [m]
    DC
    IKU
    1880.0
    [m]
    DC
    IKU
    1900.0
    [m]
    DC
    IKU
    1920.0
    [m]
    DC
    IKU
    1930.0
    [m]
    DC
    IKU
    1940.0
    [m]
    DC
    IKU
    1960.0
    [m]
    DC
    IKU
    1970.0
    [m]
    DC
    IKU
    1980.0
    [m]
    DC
    IKU
    1985.0
    [m]
    DC
    IKU
    1990.0
    [m]
    DC
    IKU
    1995.0
    [m]
    DC
    IKU
    2005.0
    [m]
    DC
    IKU
    2015.0
    [m]
    DC
    IKU
    2020.0
    [m]
    DC
    IKU
    2025.0
    [m]
    DC
    IKU
    2030.0
    [m]
    DC
    IKU
    2035.0
    [m]
    DC
    IKU
    2055.0
    [m]
    DC
    IKU
    2060.0
    [m]
    DC
    IKU
    2070.0
    [m]
    DC
    IKU
    2075.0
    [m]
    DC
    IKU
    2085.0
    [m]
    DC
    IKU
    2095.0
    [m]
    DC
    IKU
    2115.0
    [m]
    DC
    IKU
    2130.0
    [m]
    DC
    IKU
    2135.0
    [m]
    DC
    IKU
    2140.0
    [m]
    DC
    IKU
    2155.0
    [m]
    DC
    IKU
    2175.0
    [m]
    DC
    IKU
    2193.0
    [m]
    DC
    IKU
    2214.0
    [m]
    DC
    IKU
    2235.0
    [m]
    DC
    IKU
    2256.0
    [m]
    DC
    IKU
    2277.0
    [m]
    DC
    IKU
    2298.0
    [m]
    DC
    IKU
    2319.0
    [m]
    DC
    IKU
    2340.0
    [m]
    DC
    IKU
    2361.0
    [m]
    DC
    IKU
    2382.0
    [m]
    DC
    IKU
    2421.0
    [m]
    DC
    IKU
    2442.0
    [m]
    DC
    IKU
    2445.0
    [m]
    DC
    IKU
    2463.0
    [m]
    DC
    IKU
    2481.0
    [m]
    DC
    IKU
    2502.0
    [m]
    DC
    IKU
    2514.0
    [m]
    DC
    IKU
    2520.0
    [m]
    DC
    IKU
    2541.0
    [m]
    DC
    IKU
    2562.0
    [m]
    DC
    IKU
    2583.0
    [m]
    DC
    IKU
    2601.0
    [m]
    DC
    IKU
    2622.0
    [m]
    DC
    IKU
    2643.0
    [m]
    DC
    IKU
    2664.0
    [m]
    DC
    IKU
    2685.0
    [m]
    DC
    IKU
    2703.0
    [m]
    DC
    IKU
    2724.0
    [m]
    DC
    IKU
    2766.0
    [m]
    DC
    IKU
    2787.0
    [m]
    DC
    IKU
    2805.0
    [m]
    DC
    IKU
    2826.0
    [m]
    DC
    IKU
    2847.0
    [m]
    DC
    IKU
    2850.0
    [m]
    DC
    IKU
    2871.0
    [m]
    DC
    IKU
    2892.0
    [m]
    DC
    IKU
    2913.0
    [m]
    DC
    IKU
    2925.0
    [m]
    DC
    IKU
    2946.0
    [m]
    DC
    IKU
    2964.0
    [m]
    DC
    IKU
    2985.0
    [m]
    DC
    IKU
    3003.0
    [m]
    DC
    IKU
    3024.0
    [m]
    DC
    IKU
    3045.0
    [m]
    DC
    IKU
    3066.0
    [m]
    DC
    IKU
    3087.0
    [m]
    DC
    IKU
    3105.0
    [m]
    DC
    IKU
    3126.0
    [m]
    DC
    IKU
    3147.0
    [m]
    DC
    IKU
    3165.0
    [m]
    DC
    IKU
    3228.0
    [m]
    DC
    IKU
    3249.0
    [m]
    DC
    IKU
    3267.0
    [m]
    DC
    IKU
    3270.0
    [m]
    DC
    IKU
  • Lithostratigraphy

  • Composite logs

    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.67
  • Geochemical information

  • 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
    105.80
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    CBL
    248
    2396
    CST
    1430
    2402
    CST
    2396
    3713
    FDC CNL NGT GR CAL
    1430
    3713
    FDC GR CAL
    700
    1192
    HDT
    1430
    3713
    ISF LSS GR
    700
    1448
    ISF SON GR
    365
    778
    ISF SON MSFL GR SP CAL
    1430
    3713
    RFT
    1430
    2402
    RFT
    2396
    3713
    WST
    2980
    3699
    WST/VSP
    590
    2911
  • 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
    351.0
    36
    353.0
    0.00
    LOT
    SURF.COND.
    20
    747.0
    26
    753.0
    1.48
    LOT
    INTERM.
    13 3/8
    1405.0
    17 1/2
    1423.0
    1.82
    LOT
    INTERM.
    9 5/8
    2370.0
    12 1/4
    2378.0
    1.65
    LOT
    LINER
    7
    3720.0
    8 1/2
    3720.0
    0.00
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    639
    1.08
    59.0
    water based
    797
    1.10
    49.0
    water based
    1167
    1.22
    50.0
    water based
    1448
    1.32
    42.0
    water based
    1695
    1.33
    45.0
    water based
    2065
    1.45
    45.0
    water based
    3263
    1.32
    50.0
    water based
  • 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
    0.29