Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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16.07.2024 - 01:28
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6507/11-4

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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.
    6507/11-4
    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.
    6507/11-4
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    713 469 SP. 415
    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.
    547-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.
    38
    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,
    16.05.1987
    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.
    22.06.1987
    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.
    22.06.1989
    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.
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    288.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3045.0
    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).
    3043.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    4.7
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    106
    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.
    TILJE FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 8' 10.28'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 26' 3.45'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7224724.36
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    426544.70
    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.
    1055
  • Wellbore history

    General
    Well 6507/11-4 is located ca 3.5 km north-north west of the Midgard Field on the Halten Terrace. The objective was to test the hydrocarbon potential in Jurassic sandstones in a rotated north-south trending fault block. Shallow gas was warned at the following levels: 470-532/539- 601- and 671 m. TD was planned at 2950 m.
    Operations and results
    Wildcat well 6507/11-4 was spudded by the semi-submersible installation Treasure Saga on 16 May 1987, and drilled to TD at 3045 m in the Early Jurassic Aldra Formation (Tilje Formation). Due to excessive deviation during the first 13 m, the TGB was pulled and moved 10 m towards east where the well was re-spudded on May 17. Otherwise, drilling proceeded without significant problems. No shallow gas was encountered at the warned levels. The well was drilled with seawater and hi-vis mud down to 817 m, with gypsum / polymer mud from 817 m to 2655 m, and the remaining 8 1/2" section from 2655 m to TD with gel / polymer mud.
    The argillaceous Grip Group (Viking Group) was encountered at 2530 m, and the sandy Tomma Formation (Fangst Group) at 2676.5 m RKB. The latter consisted of two sandstone units (Garn and Ile Formations) separated by a more argillaceous unit (Not Formation). The gross sand thickness in the two units was 174 m and the porosity was good. The calculated average values of log porosity and the net to gross ratio for the Garn Formation was 24.6% and 0.96 respectively. The corresponding figures for the Ile Formation were 22.1% and 0.74. The Leka Formation (Ror Formation) consisted mainly of claystone, while claystone and sandstone were alternating in the Aldra Formation (Tilje Formation). Sporadic oil fluorescence were observed in lamellas of silty sandstones in the Late Cretaceous at 2220 m, 2265 m, and 2315 m. No shows were observed in the Jurassic sandstone units. Post-well organic geochemical analysis did not confirm the shows in Late Cretaceous, but revealed a possible occurrence of trace migrated hydrocarbons in cuttings at the base of the Melke Formation at 2675 m.
    Two cores were cut in the intervals 2564- 2593 m (Melke Formation) and 2685- 2713 m (Garn Formation). No wire line fluid samples were taken.
    The well was permanently abandoned on 22 June 1987 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]
    450.00
    3044.00
  • 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
    2564.0
    2591.8
    [m ]
    2
    2685.0
    2713.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    56.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES
  • Core photos

    Core photos
    Core photo at depth: 2564-2569m
    Core photo at depth: 2569-2574m
    Core photo at depth: 2574-2579m
    Core photo at depth: 2579-2584m
    Core photo at depth: 2584-2589m
    2564-2569m
    2569-2574m
    2574-2579m
    2579-2584m
    2584-2589m
    Core photo at depth: 2589-2591m
    Core photo at depth: 2685-2690m
    Core photo at depth: 2690-2695m
    Core photo at depth: 2695-2700m
    Core photo at depth: 2700-2705m
    2589-2591m
    2685-2690m
    2690-2695m
    2695-2700m
    2700-2705m
    Core photo at depth: 2705-2710m
    Core photo at depth: 2710-2713m
    Core photo at depth:  
    Core photo at depth:  
    Core photo at depth:  
    2705-2710m
    2710-2713m
  • Palynological slides at the Norwegian Offshore Directorate

    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1690.0
    [m]
    DC
    STRAT
    1716.0
    [m]
    SWC
    STRAT
    1753.0
    [m]
    SWC
    STRAT
    1770.0
    [m]
    DC
    STRAT
    1803.0
    [m]
    SWC
    STRAT
    1823.0
    [m]
    SWC
    STRAT
    1828.0
    [m]
    SWC
    STRAT
    1857.0
    [m]
    SWC
    STRAT
    1862.0
    [m]
    SWC
    STRAT
    1863.5
    [m]
    SWC
    STRAT
    1910.0
    [m]
    DC
    STRAT
    1940.0
    [m]
    DC
    STRAT
    1990.0
    [m]
    DC
    STRAT
    2016.5
    [m]
    SWC
    STRAT
    2018.0
    [m]
    SWC
    STRAT
    2046.0
    [m]
    SWC
    STRAT
    2063.0
    [m]
    SWC
    STRAT
    2170.0
    [m]
    DC
    STRAT
    2180.0
    [m]
    DC
    STRAT
    2190.0
    [m]
    DC
    STRAT
    2200.0
    [m]
    DC
    STRAT
    2210.0
    [m]
    DC
    STRAT
    2221.0
    [m]
    SWC
    STRAT
    2230.0
    [m]
    DC
    STRAT
    2240.0
    [m]
    DC
    STRAT
    2255.0
    [m]
    SWC
    STRAT
    2270.0
    [m]
    DC
    STRAT
    2283.0
    [m]
    SWC
    STRAT
    2290.0
    [m]
    DC
    STRAT
    2300.0
    [m]
    DC
    STRAT
    2312.5
    [m]
    SWC
    STRAT
    2330.0
    [m]
    DC
    STRAT
    2348.0
    [m]
    SWC
    STRAT
    2360.0
    [m]
    DC
    STRAT
    2367.5
    [m]
    SWC
    STRAT
    2380.0
    [m]
    DC
    STRAT
    2390.0
    [m]
    DC
    STRAT
    2397.5
    [m]
    SWC
    STRAT
    2410.0
    [m]
    DC
    STRAT
    2425.0
    [m]
    SWC
    STRAT
    2440.0
    [m]
    DC
    STRAT
    2450.0
    [m]
    DC
    STRAT
    2460.0
    [m]
    DC
    STRAT
    2470.0
    [m]
    SWC
    STRAT
    2477.0
    [m]
    SWC
    STRAT
    2483.0
    [m]
    SWC
    STRAT
    2486.0
    [m]
    SWC
    STRAT
    2500.0
    [m]
    DC
    STRAT
    2512.5
    [m]
    SWC
    STRAT
    2521.0
    [m]
    SWC
    STRAT
    2530.0
    [m]
    SWC
    STRAT
    2541.0
    [m]
    SWC
    STRAT
    2549.0
    [m]
    DC
    STRAT
    2562.0
    [m]
    SWC
    STRAT
    2566.0
    [m]
    C
    STRAT
    2579.1
    [m]
    C
    STRAT
    2584.5
    [m]
    SWC
    STRAT
    2591.0
    [m]
    C
    STRAT
    2600.0
    [m]
    DC
    STRAT
    2610.0
    [m]
    SWC
    STRAT
    2630.0
    [m]
    DC
    STRAT
    2642.0
    [m]
    SWC
    STRAT
    2660.0
    [m]
    DC
    STRAT
    2675.0
    [m]
    SWC
    STRAT
    2685.1
    [m]
    C
    STRAT
    2687.2
    [m]
    C
    STRAT
    2733.0
    [m]
    SWC
    STRAT
    2745.0
    [m]
    SWC
    STRAT
    2751.3
    [m]
    SWC
    STRAT
    2759.0
    [m]
    DC
    STRAT
    2771.0
    [m]
    DC
    STRAT
    2783.0
    [m]
    DC
    STRAT
    2792.0
    [m]
    DC
    STRAT
    2801.0
    [m]
    DC
    STRAT
    2816.0
    [m]
    SWC
    STRAT
    2838.0
    [m]
    SWC
    STRAT
    2854.5
    [m]
    SWC
    STRAT
    2872.5
    [m]
    SWC
    STRAT
    2887.5
    [m]
    SWC
    STRAT
    2900.0
    [m]
    DC
    STRAT
    2909.0
    [m]
    DC
    STRAT
    2918.0
    [m]
    DC
    STRAT
    2930.0
    [m]
    DC
    STRAT
    2939.0
    [m]
    DC
    STRAT
    2949.0
    [m]
    SWC
    STRAT
    2966.5
    [m]
    SWC
    STRAT
    2984.0
    [m]
    DC
    STRAT
    2991.0
    [m]
    SWC
    STRAT
    2999.0
    [m]
    DC
    STRAT
    3008.0
    [m]
    DC
    STRAT
    3020.0
    [m]
    DC
    STRAT
    3028.0
    [m]
    SWC
    STRAT
    3041.0
    [m]
    DC
    STRAT
    3044.0
    [m]
    DC
    STRAT
  • Lithostratigraphy

    Lithostratigraphy
    Top depth [mMD RKB]
    Lithostrat. unit
    314
    314
    1380
    2015
    2015
    2066
    2135
    2522
    2530
    2530
    2535
    2677
    2677
    2732
    2747
    2866
    2866
    2992
  • Geochemical information

    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.09
    pdf
    0.41
    pdf
    6.34
    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
    5.48
    pdf
    4.08
    pdf
    13.11
  • Logs

    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL VDL GR
    453
    1488
    ACBL VDL GR
    1210
    2500
    CDL GR CAL
    1488
    2369
    CNL CDL GR CAL
    2500
    3041
    COREGUN
    1525
    2489
    COREGUN
    2805
    3033
    DENSITY
    2500
    3041
    DIFL LSBHC GR CAL
    1488
    2389
    DIFL LSBHC GR CAL
    2335
    2518
    DIFL LSBHC GR CAL
    2500
    3041
    FMT PRESSURE
    2687
    3025
    MWD - GR RES DIR TEMP
    444
    3045
    SHDT
    2513
    3039
    SPECTRALOG
    2500
    3036
    VSP
    2501
    3041
  • 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
    436.0
    36
    444.0
    0.00
    LOT
    SURF.COND.
    20
    802.0
    26
    817.0
    1.49
    LOT
    INTERM.
    13 3/8
    1489.0
    17 1/2
    1506.0
    1.70
    LOT
    INTERM.
    9 5/8
    2503.0
    12 1/4
    2518.0
    1.80
    LOT
  • Drilling mud

    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    817
    1.13
    10.0
    16.8
    WATER BASED
    25.05.1987
    817
    1.10
    25.0
    21.1
    WATER BASED
    29.05.1987
    1063
    1.10
    19.0
    9.6
    WATER BASED
    29.05.1987
    1281
    1.11
    14.0
    8.2
    WATER BASED
    01.06.1987
    1506
    1.14
    15.0
    5.8
    WATER BASED
    01.06.1987
    1740
    1.25
    17.0
    8.2
    WATER BASED
    01.06.1987
    1929
    1.35
    23.0
    9.1
    WATER BASED
    03.06.1987
    2179
    1.60
    30.0
    10.1
    WATER BASED
    04.06.1987
    2399
    1.64
    27.0
    9.6
    WATER BASED
    04.06.1987
    2518
    1.64
    20.0
    7.2
    WATER BASED
    09.06.1987
    2518
    1.64
    25.0
    12.5
    WATER BASED
    09.06.1987
    2518
    1.69
    26.0
    9.6
    WATER BASED
    09.06.1987
    2518
    1.64
    20.0
    7.2
    WATER BASED
    09.06.1987
    2518
    1.66
    21.0
    7.2
    WATER BASED
    11.06.1987
    2518
    1.66
    22.0
    7.2
    WATER BASED
    12.06.1987
    2518
    1.66
    21.0
    6.8
    WATER BASED
    09.06.1987
    2550
    1.30
    13.0
    6.8
    WATER BASED
    16.06.1987
    2581
    1.30
    17.0
    7.7
    WATER BASED
    15.06.1987
    2655
    1.30
    16.0
    6.8
    WATER BASED
    15.06.1987
    2713
    1.31
    14.0
    7.2
    WATER BASED
    16.06.1987
    2883
    1.30
    15.0
    6.3
    WATER BASED
    16.06.1987
    2992
    1.30
    16.0
    5.8
    WATER BASED
    18.06.1987
    3045
    1.30
    17.0
    7.7
    WATER BASED
    18.06.1987
    3045
    1.30
    17.0
    7.7
    WATER BASED
    24.06.1987
  • 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
    0.28