Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
Factpages Norwegian Offshore Directorate
sodir.no    Norsk
sodir.no          Norsk
11.11.2024 - 01:26
Time of last synchronization with Norwegian Offshore Directorate's internal systems

6507/7-14 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.
    6507/7-14 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.
    6507/7-14
    Seismic location
    Position of spud location on seismic survey lines. SP: shotpoint.
    Survey RD0701M01 inline 10519 & crossline 7637
    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.
    1309-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.
    105
    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,
    14.06.2010
    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.
    26.09.2010
    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.
    26.09.2012
    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.
    17.10.2012
    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
    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.
    344.0
    Total depth (MD) [m RKB]
    Total measured length of wellbore from kelly bushing to total depth (driller's depth).
    4534.0
    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).
    4477.0
    Maximum inclination [°]
    Maximum deviation, in degrees, from a vertical well path.Shown only for released wells.
    22.4
    Bottom hole temperature [°C]
    Estimated temperature at final total depth of the wellbore. Shown only for released wells. See discription.
    162
    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' 35.84'' N
    EW degrees
    Geographic coordinate of the wellhead, east-west degrees.
    7° 10' 28.05'' E
    NS UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, north-south.
    7257411.95
    EW UTM [m]
    Universal Transverse Mercator coordinate of the wellhead, east-west.
    415293.97
    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.
    6367

  • Wellbore history
    General
    The Zidane 6507/7-14 S well was drilled on the Revfall Fault Complex on the Dønna Terrace in the Norwegian Sea,
    The primary objective was to test the hydrocarbon potential in the Middle Jurassic Fangst Group; Garn and Ile Formations. Secondary objectives were to test the hydrocarbon potential the Lower Cretaceous Lange Formation sandstone and the Lower Jurassic Tilje Formation.
    Operations and results
    Wildcat well 6507/7-14 S was spudded with the semi-submersible installation Bredford Dolphin on 26 September 2010 and drilled to TD at 4534 m (4477.5 m TVD) in the Early Jurassic Tilje Formation. No significant problems were encountered in the operations. The well was drilled with seawater and sweeps down to 1301 m, with Performadril water based mud from 1301 m to 2200 m, with HT Performadril mud containing 4.5 - 7% glycol from 2200 m to 3289 m, and with XP-07 oil based mud from 3289 m to TD.
    The Fangst Group, Garn Formation was encountered at 4219 m (4163.7 m TVD).The well proved a gas column in the Garn and Ile Formations with a gas down-to contact at 4381 m (4325 m TVD). The Garn Formation is 87 m thick and consists predominantly of sandstone. The Ile Formation is 65 m thick, consisting of interbedded sandstone, claystone and siltstone with poor reservoir properties. Lange Formation sandstone was encountered but proved only some residual gas. The Tilje Formation sandstone was water bearing. Weak oil shows in the form of light-coloured fluorescence were recorded in the gas-bearing reservoir; otherwise there were no oil shows reported from the well.
    A core was cut from 4221 to 4275.6 m. Core depths should be shifted 2.7 m down as compared to loggers´ depth. Plug data from the one-metre ends was available at the time of testing and these showed large permeability contrasts with some intervals having permeability of several hundred milliDarcy. Wire line fluid samples were acquired at 4226.45 m (gas), 4483.62 m (water), 4365.2 m (gas, gas+filtrate in one sample).
    The well was permanently abandoned on 26 September 2010 as a gas discovery.
    Testing
    The well was production tested (DST). The test produced 1200 000 Sm3of gas, 47 Sm3 condensate, and 16 m3 water (condensed water) per day through a 36/64 inch choke. The gas was very dry with a separator GOR of 22600 Sm3/Sm3, a gravity of 0.647 (air = 1) and 4.5% CO2. The maximum temperature recorded was 154 deg C, but due to high draw-down the initial reservoir temperature was estimated by different extrapolation techniques to be 151degC.

  • 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]
    1320.00
    4534.50

  • 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
    4221.0
    4275.6
    [m ]
    Cores at the Norwegian Offshore Directorate
    Total core sample length [m]
    54.6
    Cores at the Norwegian Offshore Directorate
    Cores available for sampling?
    YES

  • Lithostratigraphy

  • Drill stem tests (DST)
    Drill stem tests (DST)
    Test number
    From depth MD
    [m]
    To depth MD
    [m]
    Choke size
    [mm]
    1.0
    4219
    4289
    14.3
    Drill stem tests (DST)
    Test number
    Final shut-in pressure
    [MPa]
    Final flow pressure
    [MPa]
    Bottom hole pressure
    [MPa]
    Downhole temperature
    [°C]
    1.0
    44.000
    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
    1200000
    0.647
    22600

  • Logs
    Logs
    Log type
    Log top depth [m]
    Log bottom depth [m]
    AIT APS LDS HNGS
    3940
    4534
    ECRD
    4282
    4282
    MDT
    4226
    4282
    MDT
    4281
    4282
    MDT
    4296
    4510
    MSCT
    4279
    4373
    MWD - BAT SONIC DEN NEU DIR
    2200
    3947
    MWD - DDS PWD DIR
    448
    1301
    MWD - DIR
    369
    448
    MWD - GABI PWD GR RES DIR
    3223
    3289
    MWD - GABI PWD GR RES PCAL
    2200
    3947
    MWD - GM PWD RES BAT SON DEN NEU
    3947
    4534
    MWD - GR RES PWD BAT SON DIR
    448
    2200
    MWD - PWD GR RES DIR
    3180
    3289
    OBMI MSIP
    3938
    4535
    VSI-4
    1137
    4324
    XPT CMR AT
    3940
    4387

  • 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
    369.0
    36
    369.0
    0.00
    LOT
    INTERM.
    20
    448.0
    20
    1301.0
    0.00
    LOT
    INTERM.
    20
    1294.0
    20
    1301.0
    0.00
    INTERM.
    13 3/8
    2194.0
    17 1/2
    2200.0
    1.95
    LOT
    INTERM.
    9 5/8
    3938.0
    12 1/4
    3947.0
    1.96
    LOT
    LINER
    7
    4534.0
    8 1/2
    4534.0
    0.00
    LOT

  • Drilling mud
    Drilling mud
    Depth MD [m]
    Mud weight [g/cm3]
    Visc. [mPa.s]
    Yield point [Pa]
    Mud type
    Date measured
    1301
    1.36
    36.0
    PERFORMADRIL
    1444
    1.35
    30.0
    PERFORMADRIL
    2200
    1.55
    49.0
    PERFORMADRIL
    2741
    1.55
    55.0
    PERFORMADRIL
    3134
    1.55
    59.0
    PERFORMADRIL
    3258
    1.55
    41.0
    PERFORMADRIL
    3289
    1.64
    28.0
    XP-07 Yellow
    3412
    1.64
    57.0
    XP-07 Yellow
    3947
    1.64
    31.0
    XP-07 Yellow
    4221
    1.70
    32.0
    XP-07 Yellow
    4534
    1.71
    38.0
    XP-07 Yellow

  • 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