Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
25.11.2024 - 01:30
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6507/11-5 S

Export: PDF icon PDF

  • General information
    General information
    Attribute Value
    Wellbore name
    Official name of wellbore based on Norwegian Offshore Directorate guidelines for designation of wells and wellbores.
    6507/11-5 S
    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.
    RE-CLASS TO DEV
    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.
    6507/11-5
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    SG 8758-inline 530 & crossline 434
    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.
    Den norske stats oljeselskap a.s
    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.
    904-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.
    54
    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,
    05.09.1997
    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.
    28.10.1997
    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.
    28.10.1999
    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.
    07.11.2005
    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.
    APPRAISAL
    Reclassified to 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
    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.
    256.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    2695.0
    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).
    2599.5
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    21
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    93
    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.
    ROR FM
    Geodetic datum
    Reference system for coordinates. Example of legal values: ED50.
    ED50
    NS degrees
    Geographic coordinate of the wellhead, north-south degrees.
    65° 0' 18.57'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 33' 25.23'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7209986.27
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    431967.60
    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.
    3193

  • Wellbore history
    General
    The Midgard field is situated in the northeastern part of the Halten Terrace on a north south trending horst system, which is separated into 4 major segments. Four wells have been drilled on the Midgard Field, one in each of the segments Alfa, Beta, Gamma and Delta. Well 6507/11-5S was drilled as an appraisal well in the Gamma segment. The main objective of the well was to confirm the oil zone in the Ile Formation and to become a future gas producer on the Midgard field. The well should collect data on reservoir quality and fluid distribution related to both the oil and gas zones in the Midgard field.
    Operations and results
    Wildcat well 6507/11-5 S was spudded with the semi-submersible installation Deepsea Trym on 5 September 1997 and drilled to TD at 2695 m in the Middle Jurassic Ror Formation. Major operational problems were encountered leading to significant downtime. Firstly, one day was lost when the well drilled into shallow gas class II at 582 m. The well was killed and a cement plug was set. The 20" casing had to be set above the shallow gas zone. Second, fourteen days were lost due to heave compensator failures. Third, three days were lost when logging tools got stuck and failures on logging equipment appeared. The well was vertical down to 700 m where it built angle to 19.5 deg at 1350 m. This angle was kept down to TD. The well was drilled with seawater and hi-vis pills down to 547 m and with KCl/PAC mud from 547 m to TD.
    The 6507 /11-5 S well proved 114 m TVD of gas and 11.5 m TVD of oil in the Fangst Group. This was deduced from FMT sampling and petrophysical evaluation of wire line logs. The GOC was found at 2605 m (2515 m TVD RKB) and the OWC at 2617.4 m (2526.5 m TVD RKB). Three wire line fluid samples were taken in Ile (FMT gas sample at 2592.9 m, RCI oil sample at 2608.3 m, and FMT water sample at 2622.1 m), and one in Garn (FMT gas sample at 2500 m).
    The well was suspended on 28 October as an oil and gas appraisal well. It was re-entered in January 2000 and taken in use as a gas producer.
    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]
    560.00
    2484.00

  • 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
    2488.0
    2508.0
    [m ]
    2
    2508.0
    2534.7
    [m ]
    3
    2535.0
    2539.6
    [m ]
    4
    2541.0
    2554.0
    [m ]
    5
    2554.0
    2582.0
    [m ]
    6
    2582.0
    2608.5
    [m ]
    7
    2609.0
    2645.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    155.0
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Core photos
    Core photos
    Core photo at depth: 2488-2493m
    Core photo at depth: 2493-2498m
    Core photo at depth: 2498-2503m
    Core photo at depth: 2503-2508m
    Core photo at depth: 2508-2513m
    2488-2493m
    2493-2498m
    2498-2503m
    2503-2508m
    2508-2513m
    Core photo at depth: 2513-2518m
    Core photo at depth: 2518-2523m
    Core photo at depth: 2523-2528m
    Core photo at depth: 2528-2533m
    Core photo at depth: 2533-2534m
    2513-2518m
    2518-2523m
    2523-2528m
    2528-2533m
    2533-2534m
    Core photo at depth: 2535-2539m
    Core photo at depth: 2541-2546m
    Core photo at depth: 2546-2551m
    Core photo at depth: 2551-2554m
    Core photo at depth: 2554-2559m
    2535-2539m
    2541-2546m
    2546-2551m
    2551-2554m
    2554-2559m
    Core photo at depth: 2559-2564m
    Core photo at depth: 2564-2569m
    Core photo at depth: 2569-2574m
    Core photo at depth: 2574-2579m
    Core photo at depth: 2579-2582m
    2559-2564m
    2564-2569m
    2569-2574m
    2574-2579m
    2579-2582m
    Core photo at depth: 2582-2587m
    Core photo at depth: 2587-2592m
    Core photo at depth: 2592-2597m
    Core photo at depth: 2597-2602m
    Core photo at depth: 2602-2607m
    2582-2587m
    2587-2592m
    2592-2597m
    2597-2602m
    2602-2607m
    Core photo at depth: 2607-2608m
    Core photo at depth: 2609-2514m
    Core photo at depth: 2614-2619m
    Core photo at depth: 2619-2624m
    Core photo at depth: 2624-2629m
    2607-2608m
    2609-2514m
    2614-2619m
    2619-2624m
    2624-2629m

  • Palynological slides at the Norwegian Offshore Directorate
    Palynological slides at the Norwegian Offshore Directorate
    Sample depth
    Depth unit
    Sample type
    Laboratory
    1710.0
    [m]
    DC
    RRI
    1720.0
    [m]
    DC
    RRI
    1740.0
    [m]
    DC
    RRI
    1750.0
    [m]
    DC
    RRI
    1770.0
    [m]
    DC
    RRI
    1780.0
    [m]
    DC
    RRI
    1800.0
    [m]
    DC
    RRI
    1810.0
    [m]
    DC
    RRI
    1830.0
    [m]
    DC
    RRI
    1840.0
    [m]
    DC
    RRI
    1860.0
    [m]
    DC
    RRI
    1870.0
    [m]
    DC
    RRI
    1890.0
    [m]
    DC
    RRI
    1900.0
    [m]
    DC
    RRI
    1920.0
    [m]
    DC
    RRI
    1930.0
    [m]
    DC
    RRI
    1950.0
    [m]
    DC
    RRI
    1960.0
    [m]
    DC
    RRI
    1980.0
    [m]
    DC
    RRI
    1990.0
    [m]
    DC
    RRI
    2000.0
    [m]
    DC
    RRI
    2020.0
    [m]
    DC
    RRI
    2040.0
    [m]
    DC
    RRI
    2050.0
    [m]
    DC
    RRI
    2070.0
    [m]
    DC
    RRI
    2090.0
    [m]
    DC
    RRI
    2100.0
    [m]
    DC
    RRI
    2110.0
    [m]
    DC
    RRI
    2130.0
    [m]
    DC
    RRI
    2140.0
    [m]
    DC
    RRI
    2160.0
    [m]
    DC
    RRI
    2170.0
    [m]
    DC
    RRI
    2190.0
    [m]
    DC
    RRI
    2200.0
    [m]
    DC
    RRI
    2230.0
    [m]
    DC
    RRI
    2250.0
    [m]
    DC
    RRI
    2260.0
    [m]
    DC
    RRI
    2270.0
    [m]
    DC
    RRI
    2290.0
    [m]
    DC
    RRI
    2313.0
    [m]
    DC
    RRI
    2325.0
    [m]
    DC
    RRI
    2340.0
    [m]
    DC
    RRI
    2355.0
    [m]
    DC
    RRI
    2370.0
    [m]
    DC
    RRI
    2373.0
    [m]
    DC
    RRI
    2382.0
    [m]
    DC
    RRI
    2391.0
    [m]
    DC
    RRI
    2400.0
    [m]
    DC
    RRI
    2403.0
    [m]
    DC
    RRI
    2412.0
    [m]
    DC
    RRI
    2418.0
    [m]
    DC
    RRI
    2424.0
    [m]
    DC
    RRI
    2430.0
    [m]
    DC
    RRI
    2439.0
    [m]
    DC
    RRI
    2442.0
    [m]
    DC
    RRI
    2448.0
    [m]
    DC
    RRI
    2457.0
    [m]
    DC
    RRI
    2460.0
    [m]
    DC
    RRI
    2463.0
    [m]
    DC
    RRI
    2472.0
    [m]
    DC
    RRI
    2478.0
    [m]
    DC
    RRI
    2484.0
    [m]
    DC
    RRI
    2488.1
    [m]
    C
    RRI
    2495.0
    [m]
    C
    RRI
    2499.8
    [m]
    C
    RRI
    2528.0
    [m]
    C
    RRI
    2535.4
    [m]
    C
    RRI
    2541.1
    [m]
    C
    RRI
    2546.8
    [m]
    C
    RRI
    2550.9
    [m]
    C
    RRI
    2554.5
    [m]
    C
    RRI
    2559.8
    [m]
    C
    RRI
    2572.0
    [m]
    C
    RRI
    2576.9
    [m]
    C
    RRI
    2582.1
    [m]
    C
    RRI
    2588.6
    [m]
    C
    RRI
    2594.8
    [m]
    C
    RRI
    2600.3
    [m]
    C
    RRI
    2612.5
    [m]
    C
    RRI
    2618.8
    [m]
    C
    RRI
    2623.6
    [m]
    C
    RRI
    2629.7
    [m]
    C
    RRI
    2636.7
    [m]
    C
    RRI
    2640.3
    [m]
    C
    RRI
    2644.3
    [m]
    C
    RRI

  • Lithostratigraphy

  • 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
    2.70
    pdf
    22.19

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    DLL MLL MAC DSL CHT
    2478
    2693
    FMT QD GR CHT
    2500
    2500
    FMT QD GR CHT
    2592
    2592
    FMT QD GR CHT
    2622
    2622
    MWD
    281
    2695
    RCI GR TTRM
    2485
    2523
    VSP GR CHT
    1378
    2690
    ZDL CND GR CHT
    2478
    2692

  • 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
    340.0
    36
    342.0
    0.00
    LOT
    SURF.COND.
    20
    542.0
    26
    544.0
    1.30
    LOT
    INTERM.
    13 3/8
    1533.0
    17 1/2
    1534.0
    1.90
    LOT
    INTERM.
    9 5/8
    2479.0
    12 1/4
    2480.0
    0.00
    LOT
    OPEN HOLE
    2695.0
    8 1/2
    2695.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1536
    1.18
    21.0
    QUADRILL
    1598
    1.39
    DUMMY
    2100
    1.55
    32.0
    QUADRILL
    2484
    1.20
    24.0
    QUADRILL
    2508
    1.20
    20.0
    QUADRILL
    2541
    1.20
    24.0
    QUADRILL
    2554
    1.20
    18.0
    QUADRILL
    2696
    1.20
    17.0
    QUADRILL

  • 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