Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
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28.04.2024 - 01:35
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6507/7-15 S

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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.
    6507/7-15 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).
    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
    Press release
    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.
    6507/7-15
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Survey RD07M1 inline 10690 & crossline 7523
    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.
    RWE Dea Norge AS
    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.
    1380-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.
    115
    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,
    09.01.2012
    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.
    02.05.2012
    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.
    02.05.2014
    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.
    02.05.2014
    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
    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.
    YES
    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.
    FANGST GP
    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.
    EARLY 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.
    TILJE FM
    Kelly bushing elevation [m]
    Elevation of the rotary kelly bushing (RKB) above mean sea level.
    18.0
    Water depth [m]
    Depth in metres betweem mean sea level and sea floor.
    399.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4567.0
    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).
    4552.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    11.9
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    165
    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° 25' 31.81'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 5' 56.11'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7257390.90
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    411785.99
    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.
    6730

  • Wellbore history
    General
    Well 6507/7-15 S was drilled on the Zidane West prospect between the Heidrun Field and the 6506/6-1 Bella Donna discovery in the Haltenbanken area of the Norwegian Sea. The primary target was the Middle Jurassic Fangst Group; Garn and Ile Formations. Secondary target levels were the Lower Cretaceous Lange Formation sandstone and the
    Lower Jurassic Tilje Formation.
    Operations and results
    Wildcat well 6507/7-15 S was spudded with the semi-submersible installation West Alpha on 9 January 2012 and drilled to TD at 4567 m (4552 m TVD) in the Early Jurassic Tilje Formation. A 9 7/8" shallow gas pilot hole was drilled from 496 m to 649 m and shallow gas was observed at 640 - 644 m. The 26" hole was drilled to 596 m and the 20" casing was set at 594 m, above the shallow gas zone. Operations were stopped at 4124 m after setting of 9 5/8" casing due to leakage in the kill line and failure on a fail-safe valve. The well was plugged and the BOP was pulled, repaired and run again. Otherwise, operations went forth without significant problems. The well was drilled with seawater, bentonite and hi-vis sweeps down to 596 m, with KCl/freshwater dilution mud from 596 m to 1336 m, with Glydril mud from 1336 m to 2210 m, and with Versatherm oil based mud from 2210 m to TD
    The well encountered gas in the Lange, Garn, Ile and Tilje Formations. The Lange Formation had gas in a sandy interval from 3586.5 m (3585.5 m TVD) down to 3634 m (3632.5 m TVD) and water up to 3679.5 m (3677.5 m TVD) based on logs. Pressure testing was difficult due to poor reservoir conditions, so no conclusive gas gradient could be established. The Fangst Group contained gas from top Garn at 4266.5 m (4255 m TVD) down to 4404 m (4395 m TVD) in the Ile Formation. Formation pressure analysis proved the Garn and Ile Formations to be on the same gas gradient. A 10 m gas column was encountered in the Tilje Formation from the top at 4499 m (4485 m TVD) down to 4511 m (4497 m TVD), but within a different pressure system from the overlying formations. No fluid contacts from pressure measurements could be identified in this well, all hydrocarbon columns were penetrated in down-to settings.
    Two cores were cut from 4265 m to 4329.6 m in the Garn Formation and one core was cut from 4362 m to 4415.3 m in the Ile Formation. MDT gas samples were taken at 3627.24 m in the Lange Formation sands and at 4275.06 m, 4300.53 m, and 4320.39 m in the Garn Formation. These sample stations were sampled with an extra-large diameter probe. Two more hydrocarbon samples were taken in the Ile Formation 4381.80 m while performing a mini DST. No water samples were taken in the well.
    The well was permanently abandoned on 2 May 2012 as a gas discovery.
    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]
    600.00
    4567.00

  • 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
    4265.0
    4285.3
    [m ]
    2
    4292.0
    4329.6
    [m ]
    3
    4362.0
    4415.3
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    111.2
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT TLD APS HNGS EDTC LEHQT ECRD
    2175
    4133
    CMR HXPT EDTC LEHQT ECRD
    4250
    4567
    CMR XPT EDTC LEHQT ECRD
    3540
    3840
    LWD - DI
    417
    596
    LWD - DI GR ECD DEN CAL RES NEU
    496
    649
    LWD - ECD RES GR DI
    596
    1336
    LWD - ECD RES GR DI DT
    1336
    2210
    LWD - ECD RES GR DI DT CAL DEN N
    2210
    4133
    LWD - RES GR ECD DEN CAL NEU DI
    4116
    4567
    LWD - RES GR ECD DEN CAL NEU DI
    4133
    4265
    LWD - RES GR ECD DEN NEU DI TST
    4265
    4292
    MDT
    3627
    3627
    MRPS MRHY MRPO IFA HRMS
    4269
    4300
    MRPS MRHY MRPO IFA HRMS MRMS
    4271
    4320
    MSCT EDTC LEHQT ECRD
    3618
    3798
    MSCT EDTC LEHQT ECRD
    4289
    4544
    OMB12 GPIT PPC MSIP EDTC LEHQT E
    2175
    4133
    OMB12 GPIT PPC MSIP EDTC LEHQT E
    4123
    4567
    QAIT LDS APS ECS ILE HNGS EDTC L
    3765
    4568
    SC PO PA PS HY PO IFA MS EDTC LE
    4280
    4405
    VS14 EDTC LEHQT ECRD
    2092
    4557

  • 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
    497.0
    36
    497.0
    0.00
    SURF.COND.
    20
    594.0
    26
    596.0
    0.00
    PILOT HOLE
    649.0
    9 7/8
    649.0
    0.00
    INTERM.
    16
    1320.0
    20
    1336.0
    0.00
    INTERM.
    13 3/8
    2175.0
    17 1/2
    2210.0
    0.00
    INTERM.
    9 5/8
    4124.0
    12 1/4
    4133.0
    0.00
    OPEN HOLE
    4534.0
    8 1/2
    4534.0
    0.00

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    460
    1.50
    25.0
    Spud mud
    496
    1.04
    Spud mud
    596
    1.03
    seawater
    649
    1.04
    Spud mud
    1336
    1.13
    10.0
    KCl mud
    2210
    1.50
    18.0
    Glydril
    3665
    1.64
    46.0
    Versatherm
    4133
    1.64
    49.0
    Versatherm
    4133
    1.66
    47.0
    Versatherm
    4265
    1.80
    65.0
    Versatherm
    4265
    1.68
    59.0
    Versatherm
    4416
    1.82
    67.0
    Versatherm
    4567
    1.83
    74.0
    Versatherm
    4567
    1.60
    18.0
    Glydril
    4567
    1.83
    61.0
    Versatherm

  • 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