Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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05.11.2024 - 01:27
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6407/2-2

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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.
    6407/2-2
    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.
    6407/2-2
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    line 8271-101 SP 474
    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.
    375-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.
    76
    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,
    17.05.1983
    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.
    31.07.1983
    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.
    31.07.1985
    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.
    13.12.2005
    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/CONDENSATE
    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.
    26.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    258.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    3351.0
    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).
    3351.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    2
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    112
    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.
    LATE 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.
    GREY BEDS (INFORMAL)
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    64° 59' 39.64'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 31' 53.08'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7208809.08
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    430732.95
    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.
    16

  • Wellbore history
    General
    Well 6407/2-2 is located east on the Halten Terrace off shore Mid Norway. The well tested the southern (Gamma) fault compartment of a horst with true vertical closure below the base Cretaceous level. The gas/condensate discovery well 6507/11-1 was located on the northern (Alpha) compartment of the same structure. The primary target of the well was the middle Jurassic sandstone; secondary target was Early Jurassic sandstone.
    The well is Reference Well for the Melke Formation.
    Operations and results
    Wildcat well 6407/2-2 was spudded with the semi-submersible installation Treasure Saga on 17 May 1983 and drilled to TD at 3351 m, 71 m into the Triassic Grey Beds. After drilling the 26" hole the well was observed flowing and the mud weight was corrected. No other major problems occurred during drilling. After having drilled out of 13 3/8" casing shoe a cement plug was set from 1960 m - 1995 m, and one from 340 m - 400 m, due to temporarily plugging and abandonment of the well caused by strike The strike was efficient (no drilling progress was obtained) for 13 days, from June 6th to June 19th. The well was drilled with spud mud down to 865 m, with gypsum/polymer mud from 865 m to 1995 m, and with lignosulphonate mud from 1995 m to TD.
    The well proved mainly claystones down to the Middle Jurassic Sandstone. The Cainozoic with a total thickness of 1809 m overlies the Late Cretaceous where the topmost Maastrichtian is missing. Two hundred and forty meter of Late Cretaceous and 81.5 m of Early Cretaceous is preserved, separated by an unconformity ranging in age from Middle Santonian to Albian. High gas readings were experienced in the upper part of the Cretaceous together with heavier hydrocarbons detected for the first time in the well. A study of wire line logs, sidewalls cores and hole response indicate that the gas was overpressured, and trapped in a non-reservoir lithology. Base Cretaceous unconformity was encountered at 2409.5 m. The upper Jurassic was developed with 11.5 m of hot shales Spekk Formation and 39.5 m of silty claystones of the Melke Formation. As in other wells in the area, the Middle Jurassic Sandstone was divided by a shaly interval into an upper unit of very good reservoir properties (Garn Formation) and a lower unit of less good characteristics (Ile Formation). The upper unit was found to be gas bearing with a gas/water contact at 2516.5 m. All potential reservoir sequences below this depth were water bearing. The Åre Formation "Coal Unit" was 383 m thick and consisted of interbedded carbonaceous claystone/shale, fine sand and silt. It contained a total of 50 m of coals and shale layers.
    Twelve cores were cut, all in the Middle Jurassic sequence. Segregated FMT samples were collected at 2486 m (gas), 2512.5 m (gas), 2539.5 m (water), and 2546 m (water).
    The well was permanently abandoned on 31 July as a gas/condensate appraisal well on the Midgard Discovery.
    Testing
    One drill stem test was carried out in the interval 2476 m to 2484 m in the gas bearing Middle Jurassic Garn Formation sandstone. The test produced 1000000 Sm3 gas /day on a 60/64" choke. The gas/oil ratio was ca 5900 Sm3/Sm3. The liquid petroleum had a density of 0.756 g/cm3 (55.6 deg API).

  • Cuttings at the Norwegian Offshore Directorate
    Cuttings at the Norwegian Offshore Directorate
    Cuttings available for sampling?
    NO
    Cuttings at the Norwegian Offshore Directorate
    Cutting sample, top depth [m]
    Cutting samples, bottom depth [m]
    400.00
    3350.00

  • 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
    2461.3
    2471.1
    [m ]
    2
    2473.0
    2476.2
    [m ]
    3
    2479.0
    2497.0
    [m ]
    4
    2497.0
    2499.2
    [m ]
    5
    2501.0
    2506.4
    [m ]
    6
    2508.0
    2513.8
    [m ]
    7
    2518.0
    2527.0
    [m ]
    8
    2527.0
    2534.4
    [m ]
    9
    2536.0
    2548.0
    [m ]
    10
    2552.0
    2559.0
    [m ]
    11
    2565.0
    2579.7
    [m ]
    12
    2582.0
    2583.2
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    95.7
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2461-2466m
    Core photo at depth: 2466-2471m
    Core photo at depth: 2473-2476m
    Core photo at depth: 2479-2484m
    Core photo at depth: 2484-2489m
    2461-2466m
    2466-2471m
    2473-2476m
    2479-2484m
    2484-2489m
    Core photo at depth: 2489-2494m
    Core photo at depth: 2494-2497m
    Core photo at depth: 2497-2499m
    Core photo at depth: 2501-2506m
    Core photo at depth: 2506-2506m
    2489-2494m
    2494-2497m
    2497-2499m
    2501-2506m
    2506-2506m
    Core photo at depth: 2508-2513m
    Core photo at depth: 2513-2514m
    Core photo at depth: 2518-2523m
    Core photo at depth: 2523-2527m
    Core photo at depth: 2527-2532m
    2508-2513m
    2513-2514m
    2518-2523m
    2523-2527m
    2527-2532m
    Core photo at depth: 2532-2534m
    Core photo at depth: 2536-2541m
    Core photo at depth: 2541-2546m
    Core photo at depth: 2546-2549m
    Core photo at depth: 2552-2557m
    2532-2534m
    2536-2541m
    2541-2546m
    2546-2549m
    2552-2557m
    Core photo at depth: 2557-2559m
    Core photo at depth: 2565-2670m
    Core photo at depth: 2570-2575m
    Core photo at depth: 2575-2579m
    Core photo at depth: 2582-2583m
    2557-2559m
    2565-2670m
    2570-2575m
    2575-2579m
    2582-2583m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    2030.0
    [m]
    DC
    PAS
    2087.0
    [m]
    SWC
    PAS
    2095.0
    [m]
    DC
    PAS
    2100.0
    [m]
    SWC
    PAS
    2110.0
    [m]
    DC
    PAS
    2131.0
    [m]
    SWC
    PAS
    2140.0
    [m]
    DC
    PAS
    2153.0
    [m]
    SWC
    PAS
    2155.0
    [m]
    DC
    PAS
    2175.0
    [m]
    SWC
    PAS
    2185.0
    [m]
    DC
    PAS
    2208.0
    [m]
    SWC
    PAS
    2220.0
    [m]
    SWC
    PAS
    2236.0
    [m]
    SWC
    PAS
    2242.0
    [m]
    SWC
    PAS
    2258.0
    [m]
    SWC
    PAS
    2260.0
    [m]
    DC
    PAS
    2273.0
    [m]
    SWC
    PAS
    2280.9
    [m]
    DC
    PAS
    2293.0
    [m]
    SWC
    PAS
    2310.0
    [m]
    SWC
    PAS
    2326.0
    [m]
    SWC
    PAS
    2333.0
    [m]
    SWC
    PAS
    2347.0
    [m]
    SWC
    PAS
    2350.0
    [m]
    DC
    PAS
    2364.0
    [m]
    SWC
    PAS
    2375.0
    [m]
    SWC
    PAS
    2388.0
    [m]
    SWC
    PAS
    2396.0
    [m]
    DC
    PAS
    2410.0
    [m]
    SWC
    PAS
    2416.0
    [m]
    SWC
    PAS
    2418.0
    [m]
    SWC
    PAS
    2423.0
    [m]
    SWC
    PAS
    2426.0
    [m]
    SWC
    PAS
    2431.0
    [m]
    SWC
    PAS
    2434.5
    [m]
    SWC
    PAS
    2438.5
    [m]
    SWC
    PAS
    2444.0
    [m]
    SWC
    PAS
    2450.0
    [m]
    SWC
    PAS
    2455.5
    [m]
    SWC
    PAS
    2461.3
    [m]
    C
    PAS
    2466.8
    [m]
    C
    PAS
    2482.0
    [m]
    DC
    PAS
    2497.0
    [m]
    DC
    PAS
    2515.5
    [m]
    SWC
    PAS
    2519.8
    [m]
    C
    PAS
    2522.3
    [m]
    C
    PAS
    2526.5
    [m]
    C
    PAS
    2527.8
    [m]
    C
    PAS
    2530.2
    [m]
    C
    PAS
    2532.0
    [m]
    C
    PAS
    2532.3
    [m]
    C
    PAS
    2552.4
    [m]
    C
    PAS
    2556.5
    [m]
    C
    PAS
    2566.0
    [m]
    C
    PAS
    2582.0
    [m]
    C
    PAS
    2604.5
    [m]
    SWC
    PAS
    2618.0
    [m]
    SWC
    PAS
    2627.3
    [m]
    DC
    PAS
    2642.0
    [m]
    DC
    PAS
    2657.0
    [m]
    DC
    PAS
    2669.0
    [m]
    SWC
    PAS
    2689.0
    [m]
    SWC
    PAS
    2705.5
    [m]
    SWC
    PAS
    2718.5
    [m]
    SWC
    PAS
    2732.0
    [m]
    DC
    PAS
    2747.0
    [m]
    DC
    PAS
    2762.0
    [m]
    DC
    PAS
    2777.0
    [m]
    DC
    PAS
    2792.0
    [m]
    DC
    PAS
    2810.0
    [m]
    DC
    PAS
    2822.0
    [m]
    DC
    PAS
    2836.0
    [m]
    DC
    PAS
    2852.0
    [m]
    DC
    PAS
    2882.0
    [m]
    DC
    PAS
    2902.0
    [m]
    DC
    PAS
    2917.0
    [m]
    DC
    PAS
    2931.0
    [m]
    SWC
    PAS
    2937.0
    [m]
    DC
    PAS
    2952.0
    [m]
    DC
    PAS
    2967.0
    [m]
    DC
    PAS
    2982.0
    [m]
    DC
    PAS
    3000.0
    [m]
    SWC
    PAS
    3012.0
    [m]
    DC
    PAS
    3037.0
    [m]
    SWC
    PAS
    3050.0
    [m]
    SWC
    PAS
    3057.0
    [m]
    DC
    PAS
    3072.0
    [m]
    DC
    PAS
    3098.0
    [m]
    SWC
    PAS
    3117.0
    [m]
    DC
    PAS
    3132.0
    [m]
    DC
    PAS
    3147.0
    [m]
    DC
    PAS
    3167.0
    [m]
    SWC
    PAS
    3177.0
    [m]
    DC
    PAS
    3195.0
    [m]
    SWC
    PAS
    3205.0
    [m]
    SWC
    PAS
    3214.0
    [m]
    SWC
    PAS
    3240.0
    [m]
    SWC
    PAS
    3251.0
    [m]
    SWC
    PAS
    3267.0
    [m]
    DC
    PAS
    3282.0
    [m]
    DC
    PAS
    3307.0
    [m]
    DC
    PAS
    3322.0
    [m]
    DC
    PAS
    3337.0
    [m]
    DC
    PAS
    3350.0
    [m]
    DC
    PAS

  • 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
    2476.00
    2484.00
    CONDENSATE
    25.06.1983 - 03:00
    YES

  • Lithostratigraphy

  • Composite logs
    Composite logs
    Document name
    Document format
    Document size [MB]
    pdf
    0.58

  • Geochemical information
    Geochemical information
    Document name
    Document format
    Document size [MB]
    pdf
    0.53
    pdf
    4.17
    pdf
    0.89

  • 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
    16.89

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    2476
    2484
    23.8
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    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
    119
    994000
    0.770
    0.690

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    ACBL
    1750
    2676
    CAL
    398
    865
    CDL
    398
    865
    CDL
    860
    1986
    CDL CNL
    1954
    2697
    CDL CNL
    2676
    3345
    COREGUN
    430
    840
    COREGUN
    1975
    2722
    COREGUN
    2220
    2722
    COREGUN
    2723
    3325
    DIFL LS BHC
    398
    865
    DIFL LS BHC
    860
    1986
    DIFL LS BHC
    1966
    2698
    DIFL LS BHC
    2676
    3346
    DLL MLL
    1966
    2734
    FMT
    2462
    2721
    FMT
    2512
    0
    FMT
    2800
    3315
    GR
    0
    0
    HR DIP
    2675
    3345
    HRDIP
    1966
    2733
    SPECTRALOG
    1960
    2695
    TEMP
    329
    1917
    TEMP
    334
    1975
    VELOCITY
    398
    3346

  • 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
    398.0
    36
    398.0
    0.00
    LOT
    SURF.COND.
    20
    860.0
    26
    865.0
    1.61
    LOT
    INTERM.
    13 3/8
    1966.0
    17 1/2
    1995.0
    1.71
    LOT
    INTERM.
    9 5/8
    2676.0
    12 1/4
    2735.0
    0.00
    LOT
    OPEN HOLE
    3351.0
    8 1/2
    3351.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    490
    1.09
    50.0
    waterbased
    880
    1.11
    48.0
    waterbased
    1720
    1.27
    50.0
    waterbased
    2000
    1.40
    46.0
    waterbased
    2680
    1.48
    60.0
    waterbased
    2800
    1.17
    41.0
    waterbased
    3250
    1.15
    44.0
    waterbased

  • 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